Berkshire Hathaway Energy 10-Q 2016 Q1 Quarterly report

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

[X] Quarterly Report Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934

For the quarterly period ended March 31, 2016

or

[  ] Transition Report Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934

For the transition period from ______ to _______

Commission File Number	Exact name of registrant as specified in its charter; State or other jurisdiction of incorporation or organization	IRS Employer 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
001-5152	PACIFICORP	93-0246090
	(An Oregon Corporation)
	825 N.E. Multnomah Street
	Portland, Oregon 97232
	503-813-5645
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
333-206980	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
	N/A
	(Former name or former address, if changed from last report)

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.

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

Indicate by check mark whether the registrants have submitted electronically and posted on their corporate Web sites, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrants were required to submit and post such files). Yes  x  No  o

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer or a smaller reporting company. See the definitions of "large accelerated filer," "accelerated filer" and "smaller reporting company" in Rule 12b-2 of the Exchange Act.

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

Indicate by check mark whether the registrants are a shell company (as defined in Rule 12b-2 of the Exchange Act).

Yes  o  No  x

All shares of outstanding common stock of Berkshire Hathaway Energy Company are privately held by a limited group of investors. As of April 30, 2016, 77,391,144 shares of common stock, no par value, were outstanding.

All shares of outstanding common stock of PacifiCorp are indirectly owned by Berkshire Hathaway Energy Company. As of April 30, 2016, 357,060,915 shares of common stock, no par value, were outstanding.

All of the member's equity of MidAmerican Funding, LLC is held by its parent company, Berkshire Hathaway Energy Company, as of April 30, 2016.

All shares of outstanding common stock of MidAmerican Energy Company are owned by its parent company, MHC Inc., which is a direct, wholly owned subsidiary of MidAmerican Funding, LLC. As of April 30, 2016, 70,980,203 shares of common stock, no par value, were outstanding.

All shares of outstanding common stock of Nevada Power Company are owned by its parent company, NV Energy, Inc., which is an indirect, wholly owned subsidiary of Berkshire Hathaway Energy Company. As of April 30, 2016, 1,000 shares of common stock, $1.00 stated value, were outstanding.

All shares of outstanding common stock of Sierra Pacific Power Company are owned by its parent company, NV Energy, Inc. As of April 30, 2016, 1,000 shares of common stock, $3.75 par value, were outstanding.

This combined Form 10-Q is separately filed by Berkshire Hathaway Energy Company, PacifiCorp, MidAmerican Funding, LLC, MidAmerican Energy Company, Nevada Power Company and Sierra Pacific Power Company. Information contained herein relating to any individual company is filed by such company on its own behalf. Each company makes no representation as to information relating to the other companies.

TABLE OF CONTENTS

PART I

Item 1.	Financial Statements	1
Item 2.	Management's Discussion and Analysis of Financial Condition and Results of Operations	2
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	136
Item 4.	Controls and Procedures	136

PART II

Item 1.	Legal Proceedings	137
Item 1A.	Risk Factors	137
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	137
Item 3.	Defaults Upon Senior Securities	137
Item 4.	Mine Safety Disclosures	137
Item 5.	Other Information	137
Item 6.	Exhibits	137
Signatures		138
Exhibit Index		139

i

Definition of Abbreviations and Industry Terms

When used in Forward-Looking Statements, Part I - Items 2 through 3, and Part II - Items 1 through 6, the following terms have the definitions indicated.

Berkshire Hathaway Energy Company and Related Entities
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 Funding, MidAmerican Energy, Nevada Power and Sierra Pacific
Subsidiary Registrants	PacifiCorp, MidAmerican Funding, MidAmerican Energy, 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
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
Utilities	PacifiCorp, MidAmerican Energy Company, Nevada Power Company and Sierra Pacific Power Company
Berkshire Hathaway	Berkshire Hathaway Inc.
Topaz	Topaz Solar Farms LLC
Topaz Project	550-megawatt solar project 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
Certain Industry Terms
AESO	Alberta Electric System Operator
AFUDC	Allowance for Funds Used During Construction
AUC	Alberta Utilities Commission
CPUC	California Public Utilities Commission
GTA	General Tariff Application
EPA	United States Environmental Protection Agency
FERC	Federal Energy Regulatory Commission
GHG	Greenhouse Gases

ii

GWh	Gigawatt Hours
IPUC	Idaho Public Utilities Commission
IUB	Iowa Utilities Board
kV	Kilovolt
MW	Megawatts
MWh	Megawatt Hours
OPUC	Oregon Public Utility Commission
PUCN	Public Utilities Commission of Nevada
SEC	United States Securities and Exchange Commission
UPSC	Utah Public Service Commission
WPSC	Wyoming Public Service Commission
WUTC	Washington Utilities and Transportation Commission

iii

Forward-Looking Statements

This report contains statements that do not directly or exclusively relate to historical facts. These statements are "forward-looking statements" within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. Forward-looking statements can typically be identified by the use of forward-looking words, such as "will," "may," "could," "project," "believe," "anticipate," "expect," "estimate," "continue," "intend," "potential," "plan," "forecast" and similar terms. These statements are based upon the relevant Registrant's current intentions, assumptions, expectations and beliefs and are subject to risks, uncertainties and other important factors. Many of these factors are outside the control of each Registrant and could cause actual results to differ materially from those expressed or implied by such forward-looking statements. These factors include, among others:

• general economic, political and business conditions, as well as changes in, and compliance with, laws and regulations, including reliability and safety standards, affecting the Registrants' 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 rate cases and other proceedings conducted by regulatory commissions or other governmental and legal bodies and the Registrants' 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 distributed generation measures and programs, that could affect customer growth and usage, electricity and natural gas supply or the Registrants' ability to obtain long-term contracts with customers and suppliers;

• performance, availability and ongoing operation of the Registrants' 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;

• a high degree of variance between actual and forecasted load or generation that could impact the Registrants' 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 Registrants' 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 Registrant's respective 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;

iv

• 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 its business;

• 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, and embargoes; 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.

Further details of the potential risks and uncertainties affecting the Registrants are described in the Registrants' filings with the SEC, including Part II, Item 1A and other discussions contained in this Form 10-Q. Each Registrant undertakes no obligation to publicly update or revise any forward-looking statements, whether as a result of new information, future events or otherwise. The foregoing factors should not be construed as exclusive.

v

Item 1. Financial Statements

Berkshire Hathaway Energy Company and its subsidiaries
Report of Independent Registered Public Accounting Firm	4
Consolidated Balance Sheets	5
Consolidated Statements of Operations	7
Consolidated Statements of Comprehensive Income	8
Consolidated Statements of Changes in Equity	9
Consolidated Statements of Cash Flows	10
Notes to Consolidated Financial Statements	11
PacifiCorp and its subsidiaries
Report of Independent Registered Public Accounting Firm	44
Consolidated Balance Sheets	45
Consolidated Statements of Operations	47
Consolidated Statements of Changes in Shareholders' Equity	48
Consolidated Statements of Cash Flows	49
Notes to Consolidated Financial Statements	50
MidAmerican Energy Company
Report of Independent Registered Public Accounting Firm	65
Balance Sheets	66
Statements of Operations	68
Statements of Comprehensive Income	69
Statements of Changes in Equity	70
Statements of Cash Flows	71
Notes to Financial Statements	72
MidAmerican Funding, LLC and its subsidiaries
Report of Independent Registered Public Accounting Firm	83
Consolidated Balance Sheets	84
Consolidated Statements of Operations	86
Consolidated Statements of Comprehensive Income	87
Consolidated Statements of Changes in Equity	88
Consolidated Statements of Cash Flows	89
Notes to Consolidated Financial Statements	90
Nevada Power Company and its subsidiaries
Report of Independent Registered Public Accounting Firm	103
Consolidated Balance Sheets	104
Consolidated Statements of Operations	105
Consolidated Statements of Changes in Shareholder's Equity	106
Consolidated Statements of Cash Flows	107
Notes to Consolidated Financial Statements	108
Sierra Pacific Power Company and its subsidiaries
Report of Independent Registered Public Accounting Firm	120
Consolidated Balance Sheets	121
Consolidated Statements of Operations	122
Consolidated Statements of Changes in Shareholder's Equity	123
Consolidated Statements of Cash Flows	124
Notes to Consolidated Financial Statements	125

1

Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations

Berkshire Hathaway Energy Company and its subsidiaries	28
PacifiCorp and its subsidiaries	58
MidAmerican Funding, LLC and its subsidiaries and MidAmerican Energy Company	94
Nevada Power Company and its subsidiaries	114
Sierra Pacific Power Company and its subsidiaries	131

2

Berkshire Hathaway Energy Company and its subsidiaries

Consolidated Financial Section

3

PART I

Item 1. Financial Statements

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and Shareholders of

Berkshire Hathaway Energy Company

Des Moines, Iowa

We have reviewed the accompanying consolidated balance sheet of Berkshire Hathaway Energy Company and subsidiaries (the "Company") as of March 31, 2016, and the related consolidated statements of operations, comprehensive income, changes in equity, and cash flows for the three-month periods ended March 31, 2016 and 2015. These interim financial statements are the responsibility of the Company's management.

We conducted our reviews in accordance with the standards of the Public Company Accounting Oversight Board (United States). A review of interim financial information consists principally of applying analytical procedures and making inquiries of persons responsible for financial and accounting matters. It is substantially less in scope than an audit conducted in accordance with the standards of the Public Company Accounting Oversight Board (United States), the objective of which is the expression of an opinion regarding the financial statements taken as a whole. Accordingly, we do not express such an opinion.

Based on our reviews, we are not aware of any material modifications that should be made to such consolidated interim financial statements for them to be in conformity with accounting principles generally accepted in the United States of America.

We have previously audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the consolidated balance sheet of Berkshire Hathaway Energy Company and subsidiaries as of December 31, 2015, and the related consolidated statements of operations, comprehensive income, changes in equity, and cash flows for the year then ended (not presented herein); and in our report dated February 26, 2016, we expressed an unqualified opinion on those consolidated financial statements. In our opinion, the information set forth in the accompanying consolidated balance sheet as of December 31, 2015 is fairly stated, in all material respects, in relation to the consolidated balance sheet from which it has been derived.

/s/ Deloitte & Touche LLP

Des Moines, Iowa

May 6, 2016

4

BERKSHIRE HATHAWAY ENERGY COMPANY AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS (Unaudited)

(Amounts in millions)

	As of
	March 31,		December 31,
	2016		2015
ASSETS
Current assets:
Cash and cash equivalents	$	1,086	$	1,108
Trade receivables, net	1,613		1,785
Income taxes receivable	329		319
Inventories	902		882
Mortgage loans held for sale	246		335
Other current assets	796		814
Total current assets	4,972		5,243
Property, plant and equipment, net	61,152		60,769
Goodwill	9,145		9,076
Regulatory assets	4,182		4,155
Investments and restricted cash and investments	3,719		3,367
Other assets	1,076		1,008
Total assets	$	84,246	$	83,618

The accompanying notes are an integral part of these consolidated financial statements.

5

BERKSHIRE HATHAWAY ENERGY COMPANY AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS (Unaudited) (continued)

(Amounts in millions)

	As of
	March 31,			December 31,
	2016			2015
LIABILITIES AND EQUITY
Current liabilities:
Accounts payable	$	1,246		$	1,564
Accrued interest	486			469
Accrued property, income and other taxes	377			372
Accrued employee expenses	267			264
Regulatory liabilities	434			402
Short-term debt	1,722			974
Current portion of long-term debt	935			1,148
Other current liabilities	961			896
Total current liabilities	6,428			6,089
Regulatory liabilities	2,676			2,631
BHE senior debt	7,815			7,814
BHE junior subordinated debentures	2,444			2,944
Subsidiary debt	26,119			26,066
Deferred income taxes	12,797			12,685
Other long-term liabilities	2,843			2,854
Total liabilities	61,122			61,083
Commitments and contingencies (Note 10)
Equity:
BHE shareholders' equity:
Common stock - 115 shares authorized, no par value, 77 shares issued and outstanding	—			—
Additional paid-in capital	6,403			6,403
Retained earnings	17,396			16,906
Accumulated other comprehensive loss, net	(809		)	(908		)
Total BHE shareholders' equity	22,990			22,401
Noncontrolling interests	134			134
Total equity	23,124			22,535
Total liabilities and equity	$	84,246		$	83,618

The accompanying notes are an integral part of these consolidated financial statements.

6

BERKSHIRE HATHAWAY ENERGY COMPANY AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF OPERATIONS (Unaudited)

(Amounts in millions)

	Three-Month Periods
	Ended March 31,
	2016			2015
Operating revenue:
Energy	$	3,550		$	3,773
Real estate	491			448
Total operating revenue	4,041			4,221
Operating costs and expenses:
Energy:
Cost of sales	1,095			1,354
Operating expense	882			906
Depreciation and amortization	619			581
Real estate	492			450
Total operating costs and expenses	3,088			3,291
Operating income	953			930
Other income (expense):
Interest expense	(473		)	(472		)
Capitalized interest	11			29
Allowance for equity funds	15			31
Interest and dividend income	27			26
Other, net	10			26
Total other income (expense)	(410		)	(360		)
Income before income tax expense and equity income	543			570
Income tax expense	74			123
Equity income	26			26
Net income	495			473
Net income attributable to noncontrolling interests	5			4
Net income attributable to BHE shareholders	$	490		$	469

The accompanying notes are an integral part of these consolidated financial statements.

7

BERKSHIRE HATHAWAY ENERGY COMPANY AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Unaudited)

(Amounts in millions)

	Three-Month Periods
	Ended March 31,
	2016			2015
Net income	$	495		$	473
Other comprehensive income (loss), net of tax:
Unrecognized amounts on retirement benefits, net of tax of $6 and $8	22			22
Foreign currency translation adjustment	67			(424		)
Unrealized gains on available-for-sale securities, net of tax of $22 and $113	33			166
Unrealized (losses) gains on cash flow hedges, net of tax of $(14) and $1	(23		)	1
Total other comprehensive income (loss), net of tax	99			(235		)
Comprehensive income	594			238
Comprehensive income attributable to noncontrolling interests	5			4
Comprehensive income attributable to BHE shareholders	$	589		$	234

The accompanying notes are an integral part of these consolidated financial statements.

8

BERKSHIRE HATHAWAY ENERGY COMPANY AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY (Unaudited)

 (Amounts in millions)

	BHE Shareholders' Equity
										Accumulated
				Additional						Other
	Common			Paid-in			Retained			Comprehensive			Noncontrolling			Total
	Shares	Stock		Capital			Earnings			Loss, Net			Interests			Equity
Balance, December 31, 2014	77	$	—	$	6,423		$	14,513		$	(494	)	$	131		$	20,573
Adoption of ASC 853	—	—		—			56			—			11			67
Net income	—	—		—			469			—			3			472
Other comprehensive loss	—	—		—			—			(235		)	—			(235		)
Distributions	—	—		—			—			—			(6		)	(6		)
Common stock purchases	—	—		(3		)	(33		)	—			—			(36		)
Balance, March 31, 2015	77	$	—	$	6,420		$	15,005		$	(729	)	$	139		$	20,835
Balance, December 31, 2015	77	$	—	$	6,403		$	16,906		$	(908	)	$	134		$	22,535
Net income	—	—		—			490			—			4			494
Other comprehensive income	—	—		—			—			99			—			99
Distributions	—	—		—			—			—			(4		)	(4		)
Balance, March 31, 2016	77	$	—	$	6,403		$	17,396		$	(809	)	$	134		$	23,124

The accompanying notes are an integral part of these consolidated financial statements.

9

BERKSHIRE HATHAWAY ENERGY COMPANY AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited)

(Amounts in millions)

	Three-Month Periods
	Ended March 31,
	2016			2015
Cash flows from operating activities:
Net income	$	495		$	473
Adjustments to reconcile net income to net cash flows from operating activities:
Depreciation and amortization	626			587
Allowance for equity funds	(15		)	(31		)
Equity income, net of distributions	(16		)	(25		)
Changes in regulatory assets and liabilities	60			152
Deferred income taxes and amortization of investment tax credits	72			206
Other, net	3			(10		)
Changes in other operating assets and liabilities, net of effects from acquisitions:
Trade receivables and other assets	219			(18		)
Derivative collateral, net	(3		)	(21		)
Pension and other postretirement benefit plans	(6		)	(4		)
Accrued property, income and other taxes	(2		)	(99		)
Accounts payable and other liabilities	(73		)	(103		)
Net cash flows from operating activities	1,360			1,107
Cash flows from investing activities:
Capital expenditures	(1,027		)	(1,426		)
Acquisitions, net of cash acquired	(13		)	(59		)
Decrease in restricted cash and investments	41			12
Purchases of available-for-sale securities	(34		)	(68		)
Proceeds from sales of available-for-sale securities	61			57
Equity method investments	(273		)	(12		)
Other, net	(39		)	41
Net cash flows from investing activities	(1,284		)	(1,455		)
Cash flows from financing activities:
Repayments of BHE junior subordinated debentures	(500		)	—
Common stock purchases	—			(36		)
Proceeds from subsidiary debt	—			484
Repayments of subsidiary debt	(310		)	(353		)
Net proceeds from short-term debt	722			163
Other, net	(11		)	(19		)
Net cash flows from financing activities	(99		)	239
Effect of exchange rate changes	1			(1		)
Net change in cash and cash equivalents	(22		)	(110		)
Cash and cash equivalents at beginning of period	1,108			617
Cash and cash equivalents at end of period	$	1,086		$	507

The accompanying notes are an integral part of these consolidated financial statements.

10

BERKSHIRE HATHAWAY ENERGY COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

(1) General

Berkshire Hathaway Energy Company ("BHE") is a holding company that owns subsidiaries principally engaged in energy businesses (collectively with its subsidiaries, the "Company"). BHE is a consolidated subsidiary of Berkshire Hathaway Inc. ("Berkshire Hathaway").

The Company's operations are organized and managed as eight business segments: PacifiCorp, MidAmerican Funding, LLC ("MidAmerican Funding") (which primarily consists of MidAmerican Energy Company ("MidAmerican Energy")), NV Energy, Inc. ("NV Energy") (which primarily consists of Nevada Power Company ("Nevada Power") and Sierra Pacific Power Company ("Sierra Pacific")), Northern Powergrid Holdings Company ("Northern Powergrid") (which primarily consists of Northern Powergrid (Northeast) Limited and Northern Powergrid (Yorkshire) plc), BHE Pipeline Group (which consists of Northern Natural Gas Company ("Northern Natural Gas") and Kern River Gas Transmission Company ("Kern River")), BHE Transmission (which consists of BHE Canada Holdings Corporation ("AltaLink") (which primarily consists of AltaLink, L.P. ("ALP")) and BHE U.S. Transmission, LLC), BHE Renewables and HomeServices of America, Inc. (collectively with its subsidiaries, "HomeServices"). The Company, through these businesses, owns four utility companies in the United States serving customers in 11 states, two electricity distribution companies in Great Britain, two interstate natural gas pipeline companies in the United States, an electric transmission business in Canada, interests in electric transmission businesses in the United States, a renewable energy business primarily selling power generated from solar, wind, geothermal and hydroelectric sources under long-term contracts, the second largest residential real estate brokerage firm in the United States and one of the largest residential real estate brokerage franchise networks in the United States.

The unaudited Consolidated Financial Statements have been prepared in accordance with accounting principles generally accepted in the United States of America ("GAAP") for interim financial information and the United States Securities and Exchange Commission's rules and regulations for Form 10-Q and Article 10 of Regulation S-X. Accordingly, they do not include all of the disclosures required by GAAP for annual financial statements. Management believes the unaudited Consolidated Financial Statements contain all adjustments (consisting only of normal recurring adjustments) considered necessary for the fair presentation of the unaudited Consolidated Financial Statements as of March 31, 2016 and for the three-month periods ended March 31, 2016 and 2015. The results of operations for the three-month period ended March 31, 2016 are not necessarily indicative of the results to be expected for the full year.

The preparation of the unaudited Consolidated Financial Statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities at the date of the unaudited Consolidated Financial Statements and the reported amounts of revenue and expenses during the period. Actual results may differ from the estimates used in preparing the unaudited Consolidated Financial Statements. Note 2 of Notes to Consolidated Financial Statements included in the Company's Annual Report on Form 10-K for the year ended December 31, 2015 describes the most significant accounting policies used in the preparation of the unaudited Consolidated Financial Statements. There have been no significant changes in the Company's assumptions regarding significant accounting estimates and policies during the three-month period endedMarch 31, 2016.

(2)    New Accounting Pronouncements

In February 2016, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") No. 2016-02, which creates FASB Accounting Standards Codification ("ASC") Topic 842, "Leases" and supersedes Topic 840 "Leases." This guidance increases transparency and comparability among entities by recording lease assets and lease liabilities on the balance sheet and disclosing key information about leasing arrangements. A lessee should recognize in the balance sheet a liability to make lease payments (the lease liability) and a right-of-use asset representing its right to use the underlying asset for the lease term. The recognition, measurement, and presentation of expenses and cash flows arising from a lease by a lessee have not significantly changed from previous guidance. This guidance is effective for interim and annual reporting periods beginning after December 15, 2018, with early adoption permitted, and is required to be adopted using a modified retrospective approach. The Company is currently evaluating the impact of adopting this guidance on its Consolidated Financial Statements and disclosures included within Notes to Consolidated Financial Statements.

11

In January 2016, the FASB issued ASU No. 2016-01, which amends FASB ASC Subtopic 825-10, "Financial Instruments - Overall." The amendments in this guidance address certain aspects of recognition, measurement, presentation and disclosure of financial instruments including a requirement that all investments in equity securities that do not qualify for equity method accounting or result in consolidation of the investee be measured at fair value with changes in fair value recognized in net income. This guidance is effective for interim and annual reporting periods beginning after December 15, 2017, with early adoption not permitted, and is required to be adopted prospectively by means of a cumulative-effect adjustment to the balance sheet as of the beginning of the fiscal year of adoption. The Company is currently evaluating the impact of adopting this guidance on its Consolidated Financial Statements and disclosures included within Notes to Consolidated Financial Statements.

In May 2014, the FASB issued ASU No. 2014-09, which creates FASB ASC Topic 606, "Revenue from Contracts with Customers" and supersedes ASC Topic 605, "Revenue Recognition." The guidance replaces industry-specific guidance and establishes a single five-step model to identify and recognize revenue. The core principle of the guidance is that an entity should recognize revenue upon transfer of control of promised goods or services to customers in an amount that reflects the consideration to which an entity expects to be entitled in exchange for those goods or services. Additionally, the guidance requires the entity to disclose further quantitative and qualitative information regarding the nature and amount of revenues arising from contracts with customers, as well as other information about the significant judgments and estimates used in recognizing revenues from contracts with customers. In August 2015, the FASB issued ASU No. 2015-14, which defers the effective date of ASU No. 2014-09 one year to interim and annual reporting periods beginning after December 15, 2017. This guidance may be adopted retrospectively or under a modified retrospective method where the cumulative effect is recognized at the date of initial application. The Company is currently evaluating the impact of adopting this guidance on its Consolidated Financial Statements and disclosures included within Notes to Consolidated Financial Statements.

(3) Property, Plant and Equipment, Net

Property, plant and equipment, net consists of the following (in millions):

		As of
	Depreciable	March 31,			December 31,
	Life	2016			2015
Regulated assets:
Utility generation, transmission and distribution systems	5-80 years	$	69,880		$	69,248
Interstate natural gas pipeline assets	3-80 years	6,798			6,755
		76,678			76,003
Accumulated depreciation and amortization		(23,084		)	(22,682		)
Regulated assets, net		53,594			53,321
Nonregulated assets:
Independent power plants	5-30 years	4,781			4,751
Other assets	3-30 years	884			875
		5,665			5,626
Accumulated depreciation and amortization		(864		)	(805		)
Nonregulated assets, net		4,801			4,821
Net operating assets		58,395			58,142
Construction work-in-progress		2,757			2,627
Property, plant and equipment, net		$	61,152		$	60,769

Construction work-in-progress includes $2.3 billion as of March 31, 2016 and December 31, 2015, related to the construction of regulated assets.

12

(4) Investments and Restricted Cash and Investments

Investments and restricted cash and investments consists of the following (in millions):

	As of
	March 31,		December 31,
	2016		2015
Investments:
BYD Company Limited common stock	$	1,291	$	1,238
Rabbi trusts	384		380
Other	150		130
Total investments	1,825		1,748
Equity method investments:
Electric Transmission Texas, LLC	609		585
BHE Renewables tax equity investments	429		168
Bridger Coal Company	185		190
Other	170		160
Total equity method investments	1,393		1,103
Restricted cash and investments:
Quad Cities Station nuclear decommissioning trust funds	436		429
Solar Star and Topaz Projects	26		95
Other	161		129
Total restricted cash and investments	623		653
Total investments and restricted cash and investments	$	3,841	$	3,504
Reflected as:
Current assets	$	122	$	137
Noncurrent assets	3,719		3,367
Total investments and restricted cash and investments	$	3,841	$	3,504

Investments

BHE's investment in BYD Company Limited common stock is accounted for as an available-for-sale security with changes in fair value recognized in accumulated other comprehensive income (loss) ("AOCI"). The fair value of BHE's investment in BYD Company Limited common stock reflects a pre-tax unrealized gain of $1.1 billion and $1.0 billion as of March 31, 2016 and December 31, 2015, respectively.

13

(5) Recent Financing Transactions

Long-Term Debt

In April 2016, Sierra Pacific issued $400 million of its 2.60% General and Refunding Securities, Series U, due May 2026. The net proceeds will be used, together with cash on hand, to pay at maturity the $450 million principal amount of 6.00% General and Refunding Securities, Series M, maturing in May 2016.

In March 2016, BHE repaid at par value $500 million, plus accrued interest, of its junior subordinated debentures due December 2043.

Credit Facilities

In March 2016, Solar Star Funding, LLC amended its $320 million letter of credit facility reducing the amount available to $301 million and extending the maturity date to March 2026. As of March 31, 2016, Solar Star Funding, LLC had $284 million of letters of credit issued under this facility.

(6) Income Taxes

A reconciliation of the federal statutory income tax rate to the effective income tax rate applicable to income before income tax expense is as follows:

	Three-Month Periods
	Ended March 31,
	2016		2015
Federal statutory income tax rate	35	%	35	%
Income tax credits	(14	)	(11	)
State income tax, net of federal income tax benefit	(4	)	2
Income tax effect of foreign income	(5	)	(4	)
Equity income	2		2
Other, net	—		(2	)
Effective income tax rate	14	%	22	%

Income tax credits relate primarily to production tax credits from wind-powered generating facilities owned by MidAmerican Energy, PacifiCorp and BHE Renewables. Federal renewable electricity production tax credits are earned as energy from qualifying wind-powered generating facilities is produced and sold and are based on a per-kilowatt hour rate pursuant to the applicable federal income tax law. Wind-powered generating facilities are eligible for the credits for 10 years from the date the qualifying generating facilities are placed in-service.

Berkshire Hathaway includes the Company in its United States federal income tax return. For the three-month periods endedMarch 31,2016 and 2015, the Company did not receive or make any cash payments for income taxes from or to Berkshire Hathaway.

14

(7) Employee Benefit Plans

Domestic Operations

Net periodic benefit cost for the domestic pension and other postretirement benefit plans included the following components (in millions):

	Three-Month Periods
	Ended March 31,
	2016			2015
Pension:
Service cost	$	8		$	8
Interest cost	31			30
Expected return on plan assets	(40		)	(42		)
Net amortization	11			13
Net periodic benefit cost	$	10		$	9
Other postretirement:
Service cost	$	3		$	4
Interest cost	8			7
Expected return on plan assets	(11		)	(12		)
Net amortization	(3		)	(3		)
Net periodic benefit credit	$	(3	)	$	(4	)

Employer contributions to the domestic pension and other postretirement benefit plans are expected to be $34 million and $1 million, respectively, during 2016. As of March 31, 2016, $3 million and $- million of contributions had been made to the domestic pension and other postretirement benefit plans, respectively.

Foreign Operations

Net periodic benefit cost for the United Kingdom pension plan included the following components (in millions):

	Three-Month Periods
	Ended March 31,
	2016			2015
Service cost	$	5		$	6
Interest cost	19			20
Expected return on plan assets	(29		)	(29		)
Net amortization	12			16
Net periodic benefit cost	$	7		$	13

Employer contributions to the United Kingdom pension plan are expected to be £40 million during 2016. As of March 31, 2016, £12 million, or $17 million, of contributions had been made to the United Kingdom pension plan.

15

(8) Risk Management and Hedging Activities

The Company is exposed to the impact of market fluctuations in commodity prices, interest rates and foreign currency exchange rates. The Company is principally exposed to electricity, natural gas, coal and fuel oil commodity price risk primarily through BHE's ownership of PacifiCorp, MidAmerican Energy Company, Nevada Power Company and Sierra Pacific Power Company (the "Utilities") as they have an obligation to serve retail customer load in their regulated service territories. The Company also provides nonregulated retail electricity and natural gas services in competitive markets. The Utilities' load and generating facilities represent substantial underlying commodity positions. Exposures to commodity prices consist mainly of variations in the price of fuel required to generate electricity, wholesale electricity that is purchased and sold, and natural gas supply for retail customers. Commodity prices are subject to wide price swings as supply and demand are impacted by, among many other unpredictable items, weather, market liquidity, generating facility availability, customer usage, storage, and transmission and transportation constraints. Interest rate risk exists on variable-rate debt, future debt issuances and mortgage commitments. Additionally, the Company is exposed to foreign currency exchange rate risk from its business operations and investments in Great Britain and Canada. The Company does not engage in a material amount of proprietary trading activities.

Each of the Company's business platforms has established a risk management process that is designed to identify, assess, manage, mitigate, monitor and report each of the various types of risk involved in its business. To mitigate a portion of its commodity price risk, the Company uses commodity derivative contracts, which may include forwards, futures, options, swaps and other agreements, to effectively secure future supply or sell future production generally at fixed prices. The Company manages its interest rate risk by limiting its exposure to variable interest rates primarily through the issuance of fixed-rate long-term debt and by monitoring market changes in interest rates. Additionally, the Company may from time to time enter into interest rate derivative contracts, such as interest rate swaps or locks, forward sale commitments, or mortgage interest rate lock commitments, to mitigate the Company's exposure to interest rate risk. The Company does not hedge all of its commodity price, interest rate and foreign currency exchange rate risks, thereby exposing the unhedged portion to changes in market prices.

There have been no significant changes in the Company's accounting policies related to derivatives. Refer to Note 9 for additional information on derivative contracts.

The following table, which reflects master netting arrangements and excludes contracts that have been designated as normal under the normal purchases or normal sales exception afforded by GAAP, summarizes the fair value of the Company's derivative contracts, on a gross basis, and reconciles those amounts to the amounts presented on a net basis on the Consolidated Balance Sheets (in millions):

	Other					Other			Other
	Current			Other		Current			Long-term
	Assets			Assets		Liabilities			Liabilities			Total
As of March 31, 2016
Not designated as hedging contracts:
Commodity assets(1)	$	20		$	85	$	11		$	2		$	118
Commodity liabilities(1)	(1		)	—		(117		)	(174		)	(292		)
Interest rate assets	11			—		—			—			11
Interest rate liabilities	—			—		(5		)	(12		)	(17		)
Total	30			85		(111		)	(184		)	(180		)
Designated as hedging contracts:
Commodity assets	—			—		—			—			—
Commodity liabilities	—			—		(47		)	(26		)	(73		)
Interest rate assets	—			—		—			—			—
Interest rate liabilities	—			—		(4		)	(7		)	(11		)
Total	—			—		(51		)	(33		)	(84		)
Total derivatives	30			85		(162		)	(217		)	(264		)
Cash collateral receivable	—			—		47			66			113
Total derivatives - net basis	$	30		$	85	$	(115	)	$	(151	)	$	(151	)

16

	Other					Other			Other
	Current			Other		Current			Long-term
	Assets			Assets		Liabilities			Liabilities			Total
As of December 31, 2015
Not designated as hedging contracts:
Commodity assets(1)	$	25		$	72	$	7		$	2		$	106
Commodity liabilities(1)	(4		)	—		(113		)	(175		)	(292		)
Interest rate assets	7			—		—			—			7
Interest rate liabilities	—			—		(3		)	(6		)	(9		)
Total	28			72		(109		)	(179		)	(188		)
Designated as hedging contracts:
Commodity assets	—			—		1			2			3
Commodity liabilities	—			—		(33		)	(17		)	(50		)
Interest rate assets	—			3		—			—			3
Interest rate liabilities	—			—		(4		)	(1		)	(5		)
Total	—			3		(36		)	(16		)	(49		)
Total derivatives	28			75		(145		)	(195		)	(237		)
Cash collateral receivable	—			—		40			63			103
Total derivatives - net basis	$	28		$	75	$	(105	)	$	(132	)	$	(134	)

(1) The Company's commodity derivatives not designated as hedging contracts are generally included in regulated rates, and as of March 31, 2016 and December 31, 2015, a net regulatory asset of $253 million and $250 million, respectively, was recorded related to the net derivative liability of $174 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.

Not Designated as Hedging Contracts

The following table reconciles the beginning and ending balances of the Company's net regulatory assets and summarizes the pre-tax gains and losses on commodity derivative contracts recognized in net regulatory assets, as well as amounts reclassified to earnings (in millions):

	Three-Month Periods
	Ended March 31,
	2016			2015
Beginning balance	$	250		$	223
Changes in fair value recognized in net regulatory assets	36			60
Net gains reclassified to operating revenue	—			9
Net losses reclassified to cost of sales	(33		)	(37		)
Ending balance	$	253		$	255

17

Designated as Hedging Contracts

The Company uses commodity derivative contracts accounted for as cash flow hedges to hedge electricity and natural gas commodity prices for delivery to nonregulated customers, spring operational sales, natural gas storage and other transactions. Certain commodity derivative contracts have settled and the fair value at the date of settlement remains in AOCI and is recognized in earnings when the forecasted transactions impact earnings. The following table reconciles the beginning and ending balances of the Company's accumulated other comprehensive (income) loss (pre-tax) and summarizes pre-tax gains and losses on commodity derivative contracts designated and qualifying as cash flow hedges recognized in other comprehensive income ("OCI"), as well as amounts reclassified to earnings (in millions):

	Three-Month Periods
	Ended March 31,
	2016			2015
Beginning balance	$	46		$	32
Changes in fair value recognized in OCI	48			(8		)
Net gains reclassified to operating revenue	—			1
Net (losses) gains reclassified to cost of sales	(22		)	2
Ending balance	$	72		$	27

Realized gains and losses on hedges and hedge ineffectiveness are recognized in income as operating revenue, cost of sales, operating expense or interest expense depending upon the nature of the item being hedged. For the three-month periods ended March 31, 2016 and 2015, hedge ineffectiveness was insignificant. As of March 31, 2016, the Company had cash flow hedges with expiration dates extending through September 2025 and $51 million of pre-tax unrealized losses are forecasted to be reclassified from AOCI into earnings over the next twelve months as contracts settle.

Derivative Contract Volumes

The following table summarizes the net notional amounts of outstanding derivative contracts with fixed price terms that comprise the mark-to-market values as of (in millions):

	Unit of	March 31,		December 31,
	Measure	2016		2015
Electricity purchases	Megawatt hours	11		10
Natural gas purchases	Decatherms	360		317
Fuel purchases	Gallons	9		11
Interest rate swaps	US$	653		653
Mortgage sale commitments, net	US$	(213	)	(312	)

Credit Risk

The Utilities are exposed to counterparty credit risk associated with wholesale energy supply and marketing activities with other utilities, energy marketing companies, financial institutions and other market participants. Credit risk may be concentrated to the extent the Utilities' counterparties have similar economic, industry or other characteristics and due to direct or indirect relationships among the counterparties. Before entering into a transaction, the Utilities analyze the financial condition of each significant wholesale counterparty, establish limits on the amount of unsecured credit to be extended to each counterparty and evaluate the appropriateness of unsecured credit limits on an ongoing basis. To further mitigate wholesale counterparty credit risk, the Utilities enter into netting and collateral arrangements that may include margining and cross-product netting agreements and obtain third-party guarantees, letters of credit and cash deposits. If required, the Utilities exercise rights under these arrangements, including calling on the counterparty's credit support arrangement.

18

Collateral and Contingent Features

In accordance with industry practice, certain wholesale derivative contracts contain credit support provisions that in part base certain collateral requirements on credit ratings for senior unsecured debt as reported by one or more of the three recognized credit rating agencies. These derivative contracts may either specifically provide bilateral rights to demand cash or other security if credit exposures on a net basis exceed specified rating-dependent threshold levels ("credit-risk-related contingent features") or provide the right for counterparties to demand "adequate assurance," or in some cases terminate the contract, in the event of a material adverse change in creditworthiness. These rights can vary by contract and by counterparty. As of March 31, 2016, the applicable credit ratings from the three recognized credit rating agencies were investment grade.

The aggregate fair value of the Company's derivative contracts in liability positions with specific credit-risk-related contingent features totaled $309 million and $288 million as of March 31, 2016 and December 31, 2015, respectively, for which the Company had posted collateral of $78 million and $75 million, respectively, in the form of cash deposits. If all credit-risk-related contingent features for derivative contracts in liability positions had been triggered as of March 31, 2016 and December 31, 2015, the Company would have been required to post $220 million and $198 million, respectively, of additional collateral. The Company's collateral requirements could fluctuate considerably due to market price volatility, changes in credit ratings, changes in legislation or regulation, or other factors.

(9) Fair Value Measurements

The carrying value of the Company's cash, certain cash equivalents, receivables, payables, accrued liabilities and short-term borrowings approximates fair value because of the short-term maturity of these instruments. The Company has various financial assets and liabilities that are measured at fair value on the Consolidated Financial Statements using inputs from the three levels of the fair value hierarchy. A financial asset or liability classification within the hierarchy is determined based on the lowest level input that is significant to the fair value measurement. The three levels are as follows:

• 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.

19

The following table presents the Company's assets and liabilities recognized on the Consolidated Balance Sheets and measured at fair value on a recurring basis (in millions):

	Input Levels for Fair Value Measurements
	Level 1			Level 2			Level 3			Other(1)			Total
As of March 31, 2016
Assets:
Commodity derivatives	$	—		$	17		$	101		$	(14	)	$	104
Interest rate derivatives	—			—			11			—			11
Mortgage loans held for sale	—			237			—			—			237
Money market mutual funds(2)	504			—			—			—			504
Debt securities:
United States government obligations	142			—			—			—			142
International government obligations	—			2			—			—			2
Corporate obligations	—			34			—			—			34
Municipal obligations	—			2			—			—			2
Agency, asset and mortgage-backed obligations	—			4			—			—			4
Auction rate securities	—			—			26			—			26
Equity securities:
United States companies	242			—			—			—			242
International companies	1,298			—			—			—			1,298
Investment funds	161			—			—			—			161
	$	2,347		$	296		$	138		$	(14	)	$	2,767
Liabilities:
Commodity derivatives	$	(10	)	$	(312	)	$	(43	)	$	127		$	(238	)
Interest rate derivatives	—			(28		)	—			—			(28		)
	$	(10	)	$	(340	)	$	(43	)	$	127		$	(266	)

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	)

20

(1) Represents netting under master netting arrangements and a net cash collateral receivable of $113 million and $103 million as of March 31, 2016 and December 31, 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.

Derivative contracts are recorded on the Consolidated Balance Sheets as either assets or liabilities and are stated at estimated fair value unless they are designated as normal purchases or normal sales and qualify for the exception afforded by GAAP. When available, the fair value of derivative contracts is estimated using unadjusted quoted prices for identical contracts in the market in which the Company transacts. When quoted prices for identical contracts are not available, the Company uses forward price curves. Forward price curves represent the Company's estimates of the prices at which a buyer or seller could contract today for delivery or settlement at future dates. The Company bases its forward price curves upon market price quotations, when available, or internally developed and commercial models, with internal and external fundamental data inputs. Market price quotations are obtained from independent brokers, exchanges, direct communication with market participants and actual transactions executed by the Company. Market price quotations are generally readily obtainable for the applicable term of the Company's outstanding derivative contracts; therefore, the Company's forward price curves reflect observable market quotes. Market price quotations for certain electricity and natural gas trading hubs are not as readily obtainable due to the length of the contract. Given that limited market data exists for these contracts, as well as for those contracts that are not actively traded, the Company uses forward price curves derived from internal models based on perceived pricing relationships to major trading hubs that are based on unobservable inputs. The estimated fair value of these derivative contracts is a function of underlying forward commodity prices, interest rates, currency rates, related volatility, counterparty creditworthiness and duration of contracts. Refer to Note 8 for further discussion regarding the Company's risk management and hedging activities.

The Company's mortgage loans held for sale are valued based on independent quoted market prices, where available, or the prices of other mortgage whole loans with similar characteristics. As necessary, these prices are adjusted for typical securitization activities, including servicing value, portfolio composition, market conditions and liquidity.

The Company's investments in money market mutual funds and debt and equity securities are stated at fair value and are primarily accounted for as available-for-sale securities. When available, a readily observable quoted market price or net asset value of an identical security in an active market is used to record the fair value. In the absence of a quoted market price or net asset value of an identical security, the fair value is determined using pricing models or net asset values based on observable market inputs and quoted market prices of securities with similar characteristics. The fair value of the Company's investments in auction rate securities, where there is no current liquid market, is determined using pricing models based on available observable market data and the Company's judgment about the assumptions, including liquidity and nonperformance risks, which market participants would use when pricing the asset.

The following table reconciles the beginning and ending balances of the Company's assets and liabilities measured at fair value on a recurring basis using significant Level 3 inputs (in millions):

	Three-Month Periods
	Ended March 31,
				Interest			Auction
	Commodity			Rate			Rate
	Derivatives			Derivatives			Securities
2016:
Beginning balance	$	47		$	4		$	44
Changes included in earnings	19			25			—
Changes in fair value recognized in OCI	(6		)	—			4
Changes in fair value recognized in net regulatory assets	(6		)	—			—
Redemptions	—			—			(22		)
Settlements	4			(18		)	—
Ending balance	$	58		$	11		$	26

21

	Three-Month Periods
	Ended March 31,
				Interest			Auction
	Commodity			Rate			Rate
	Derivatives			Derivatives			Securities
2015:
Beginning balance	$	51		$	—		$	45
Changes included in earnings	8			21			—
Changes in fair value recognized in OCI	1			—			(1		)
Changes in fair value recognized in net regulatory assets	(3		)	—			—
Settlements	(8		)	(16		)	—
Transfers from Level 2	—			3			—
Ending balance	$	49		$	8		$	44

The Company's long-term debt is carried at cost on the Consolidated Balance Sheets. The fair value of the Company's long-term debt is a Level 2 fair value measurement and has been estimated based upon quoted market prices, where available, or at the present value of future cash flows discounted at rates consistent with comparable maturities with similar credit risks. The carrying value of the Company's variable-rate long-term debt approximates fair value because of the frequent repricing of these instruments at market rates. The following table presents the carrying value and estimated fair value of the Company's long-term debt (in millions):

	As of March 31, 2016				As of December 31, 2015
	Carrying		Fair		Carrying		Fair
	Value		Value		Value		Value
Long-term debt	$	37,313	$	42,878	$	37,972	$	41,785

22

(10) Commitments and Contingencies

Legal Matters

The Company is party to a variety of legal actions arising out of the normal course of business. Plaintiffs occasionally seek punitive or exemplary damages. The Company does not believe that such normal and routine litigation will have a material impact on its consolidated financial results. The Company is also involved in other kinds of legal actions, some of which assert or may assert claims or seek to impose fines, penalties and other costs in substantial amounts and are described below.

USA Power

In October 2005, prior to BHE's ownership of PacifiCorp, PacifiCorp was added as a defendant to a lawsuit originally filed in February 2005 in the Third District Court of Salt Lake County, Utah ("Third District Court") by USA Power, LLC, USA Power Partners, LLC and Spring Canyon Energy, LLC (collectively, the "Plaintiff"). The Plaintiff's complaint alleged that PacifiCorp misappropriated confidential proprietary information in violation of Utah's Uniform Trade Secrets Act and accused PacifiCorp of breach of contract and related claims in regard to the Plaintiff's 2002 and 2003 proposals to build a natural gas-fueled generating facility in Juab County, Utah. In October 2007, the Third District Court granted PacifiCorp's motion for summary judgment on all counts and dismissed the Plaintiff's claims in their entirety. In a May 2010 ruling on the Plaintiff's petition for reconsideration, the Utah Supreme Court reversed summary judgment and remanded the case back to the Third District Court for further consideration. In May 2012, a jury awarded damages to the Plaintiff for breach of contract and misappropriation of a trade secret in the amounts of $18 million for actual damages and $113 million for unjust enrichment. After considering various motions filed by the parties to expand or limit damages, interest and attorney's fees, in May 2013, the court entered a final judgment against PacifiCorp in the amount of $115 million, which includes the $113 million of aggregate damages previously awarded and amounts awarded for the Plaintiff's attorneys' fees. The final judgment also ordered that postjudgment interest accrue beginning as of the date of the April 2013 initial judgment. In May 2013, PacifiCorp posted a surety bond issued by a subsidiary of Berkshire Hathaway to secure its estimated obligation. PacifiCorp strongly disagrees with the jury's verdict and is vigorously pursuing all appellate measures. Both PacifiCorp and the Plaintiff filed appeals with the Utah Supreme Court. Briefing before the Utah Supreme Court is complete and oral arguments were heard in September 2015. As of March 31, 2016, PacifiCorp had accrued $122 million for the final judgment and postjudgment interest, and believes the likelihood of any additional material loss is remote; however, any additional awards against PacifiCorp could also have a material effect on the consolidated financial results. Any payment of damages will be at the end of the appeals process.

Environmental Laws and Regulations

The Company is subject to federal, state, local and foreign laws and regulations regarding air and water quality, renewable portfolio standards, emissions performance standards, climate change, coal combustion byproduct disposal, hazardous and solid waste disposal, protected species and other environmental matters that have the potential to impact the Company's current and future operations. The Company believes it is in material compliance with all applicable laws and regulations.

Hydroelectric Relicensing

PacifiCorp's Klamath hydroelectric system is currently operating under annual licenses with the Federal Energy Regulatory Commission ("FERC"). In February 2010, PacifiCorp, the United States Department of the Interior, the United States Department of Commerce, the state of California, the state of Oregon and various other governmental and non-governmental settlement parties signed the Klamath Hydroelectric Settlement Agreement ("KHSA"). Among other things, the KHSA provided that the United States Department of the Interior would conduct scientific and engineering studies to assess whether removal of the Klamath hydroelectric system's mainstem dams was in the public interest and would advance restoration of the Klamath Basin's salmonid fisheries. If it was determined that dam removal should proceed, dam removal would have begun no earlier than 2020.

Under the KHSA, PacifiCorp and its customers were protected from uncapped dam removal costs and liabilities. For dam removal to occur, federal legislation consistent with the KHSA was required to provide, among other things, protection for PacifiCorp from all liabilities associated with dam removal activities. As of December 31, 2015, no federal legislation had been enacted, and several parties to the KHSA initiated a dispute resolution process.

23

In February 2016, the principal parties to the KHSA (PacifiCorp, the states of California and Oregon and the United States Departments of the Interior and Commerce) executed an agreement in principle committing to explore potential amendment of the KHSA to facilitate removal of the Klamath dams through a FERC process without the need for federal legislation. Since that time, PacifiCorp, the states of California and Oregon, and the United States Departments of the Interior and Commerce have negotiated an amendment to the KHSA that was signed on April 6, 2016. Under the amended KHSA, PacifiCorp will file an application with the FERC to transfer the license for the four mainstem Klamath River hydroelectric generating facilities to a newly formed private entity, the Klamath River Renewal Corporation ("KRRC"). The KRRC will file an application to surrender the license and decommission the facilities with the FERC.

The amended KHSA provides PacifiCorp with liability protections comparable to the KHSA. The amended KHSA also limits PacifiCorp's contribution to facilities removal costs to no more than $200 million, of which up to $184 million would be collected from PacifiCorp's Oregon customers with the remainder to be collected from PacifiCorp's California customers. Additional funding of up to $250 million for facilities removal costs is to be provided by the state of California. California voters approved a water bond measure in November 2014 from which the state of California's contribution toward facilities removal costs will be drawn. If facilities removal costs exceed the combined funding that will be available from PacifiCorp's Oregon and California customers and the state of California, sufficient funds would need to be provided by the KRRC or an entity other than PacifiCorp in order for facilities removal to proceed.

If certain conditions in the amended KHSA are not satisfied and the license does not transfer to the KRRC, PacifiCorp will resume relicensing with the FERC.

Guarantees

The Company has entered into guarantees as part of the normal course of business and the sale of certain assets. These guarantees are not expected to have a material impact on the Company's consolidated financial results.

(11) Components of Other Comprehensive Income (Loss), Net

The following table shows the change in AOCI attributable to BHE shareholders by each component of OCI, net of applicable income taxes (in millions):

							Unrealized
	Unrecognized			Foreign			Gains on		Unrealized			AOCI
	Amounts on			Currency			Available-		Gains (Losses)			Attributable
	Retirement			Translation			For-Sale		on Cash			To BHE
	Benefits			Adjustment			Securities		Flow Hedges			Shareholders, Net
Balance, December 31, 2014	$	(490	)	$	(412	)	$	390	$	18		$	(494	)
Other comprehensive income (loss)	22			(424		)	166		1			(235		)
Balance, March 31, 2015	$	(468	)	$	(836	)	$	556	$	19		$	(729	)
Balance, December 31, 2015	$	(438	)	$	(1,092	)	$	615	$	7		$	(908	)
Other comprehensive income (loss)	22			67			33		(23		)	99
Balance, March 31, 2016	$	(416	)	$	(1,025	)	$	648	$	(16	)	$	(809	)

Reclassifications from AOCI to net income for the periods ended March 31, 2016 and 2015 were insignificant. For information regarding cash flow hedge reclassifications from AOCI to net income in their entirety, refer to Note 8. Additionally, refer to the "Foreign Operations" discussion in Note 7 for information about unrecognized amounts on retirement benefits reclassifications from AOCI that do not impact net income in their entirety.

24

(12) Segment Information

The Company's reportable segments with foreign operations include Northern Powergrid, whose business is principally in the United Kingdom, BHE Transmission, whose business includes operations in Canada, and BHE Renewables, whose business includes operations in the Philippines. Intersegment eliminations and adjustments, including the allocation of goodwill, have been made. Effective January 1, 2016, MidAmerican Energy transferred the assets and liabilities of its unregulated retail services business to a subsidiary of BHE. Prior period amounts have been changed to reflect this activity in BHE and Other. Information related to the Company's reportable segments is shown below (in millions):

	Three-Month Periods
	Ended March 31,
	2016		2015
Operating revenue:
PacifiCorp	$	1,252	$	1,250
MidAmerican Funding	626		727
NV Energy	615		706
Northern Powergrid	279		324
BHE Pipeline Group	315		332
BHE Transmission	158		125
BHE Renewables	139		124
HomeServices	491		448
BHE and Other(1)	166		185
Total operating revenue	$	4,041	$	4,221
Depreciation and amortization:
PacifiCorp	$	197	$	194
MidAmerican Funding	110		100
NV Energy	104		101
Northern Powergrid	50		48
BHE Pipeline Group	53		50
BHE Transmission	50		38
BHE Renewables	56		49
HomeServices	6		6
BHE and Other(1)	—		1
Total depreciation and amortization	$	626	$	587

25

	Three-Month Periods
	Ended March 31,
	2016			2015
Operating income:
PacifiCorp	$	324		$	273
MidAmerican Funding	100			101
NV Energy	89			121
Northern Powergrid	158			193
BHE Pipeline Group	192			200
BHE Transmission	76			46
BHE Renewables	24			6
HomeServices	(1		)	(2		)
BHE and Other(1)	(9		)	(8		)
Total operating income	953			930
Interest expense	(473		)	(472		)
Capitalized interest	11			29
Allowance for equity funds	15			31
Interest and dividend income	27			26
Other, net	10			26
Total income before income tax expense and equity income	$	543		$	570

Interest expense:
PacifiCorp	$	95	$	95
MidAmerican Funding	54		50
NV Energy	67		63
Northern Powergrid	36		35
BHE Pipeline Group	13		18
BHE Transmission	36		36
BHE Renewables	49		46
HomeServices	1		1
BHE and Other(1)	122		128
Total interest expense	$	473	$	472

Operating revenue by country:
United States	$	3,599	$	3,769
United Kingdom	279		324
Canada	160		127
Philippines and other	3		1
Total operating revenue by country	$	4,041	$	4,221

Income before income tax expense and equity income by country:
United States	$	358	$	358
United Kingdom	119		164
Canada	43		35
Philippines and other	23		13
Total income before income tax expense and equity income by country	$	543	$	570

26

	As of
	March 31,		December 31,
	2016		2015
Total assets:
PacifiCorp	$	23,590	$	23,550
MidAmerican Funding	16,330		16,315
NV Energy	14,438		14,656
Northern Powergrid	7,272		7,317
BHE Pipeline Group	5,101		4,953
BHE Transmission	8,136		7,553
BHE Renewables	6,156		5,892
HomeServices	1,684		1,705
BHE and Other(1)	1,539		1,677
Total assets	$	84,246	$	83,618

(1) The differences between the reportable segment amounts and the consolidated amounts, described as BHE and Other, relate principally to other entities, corporate functions and intersegment eliminations.

The following table shows the change in the carrying amount of goodwill by reportable segment for the three-month period ended March 31, 2016 (in millions):

										BHE									BHE
			MidAmerican		NV		Northern			Pipeline			BHE		BHE		Home-		and
	PacifiCorp		Funding		Energy		Powergrid			Group			Transmission		Renewables		Services		Other		Total
December 31, 2015	$	1,129	$	2,102	$	2,369	$	1,056		$	101		$	1,428	$	95	$	794	$	2	$	9,076
Acquisitions	—		—		—		—			—			—		—		3		—		3
Foreign currency translation	—		—		—		(20		)	—			91		—		—		1		72
Other	—		—		—		—			(6		)	—		—		—		—		(6		)
March 31, 2016	$	1,129	$	2,102	$	2,369	$	1,036		$	95		$	1,519	$	95	$	797	$	3	$	9,145

27

Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations

The following is management's discussion and analysis of certain significant factors that have affected the consolidated financial condition and results of operations of the Company during the periods included herein. Explanations include management's best estimate of the impact of weather, customer growth and other factors. This discussion should be read in conjunction with the Company's historical unaudited Consolidated Financial Statements and Notes to Consolidated Financial Statements in Part I, Item 1 of this Form 10-Q. The Company's actual results in the future could differ significantly from the historical results.

The Company's operations are organized and managed as eight business segments: PacifiCorp, MidAmerican Funding (which primarily consists of MidAmerican Energy), NV Energy (which primarily consists of Nevada Power and Sierra Pacific), Northern Powergrid (which primarily consists of Northern Powergrid (Northeast) Limited and Northern Powergrid (Yorkshire) plc), BHE Pipeline Group (which consists of Northern Natural Gas and Kern River), BHE Transmission (which consists of AltaLink and BHE U.S. Transmission), BHE Renewables and HomeServices. BHE, through these businesses, owns four utility companies in the United States serving customers in 11 states, two electricity distribution companies in Great Britain, two interstate natural gas pipeline companies in the United States, an electric transmission business in Canada, interests in electric transmission businesses in the United States, a renewable energy business primarily selling power generated from solar, wind, geothermal and hydroelectric sources under long-term contracts, the second largest residential real estate brokerage firm in the United States and one of the largest residential real estate brokerage franchise networks in the United States. The reportable segment financial information includes all necessary adjustments and eliminations needed to conform to the Company's significant accounting policies. The differences between the reportable segment amounts and the consolidated amounts, described as BHE and Other, relate principally to other entities, corporate functions and intersegment eliminations. Effective January 1, 2016, MidAmerican Energy transferred the assets and liabilities of its unregulated retail services business to a subsidiary of BHE. Prior period amounts have been changed to reflect this activity in BHE and Other.

Results of Operations for the First Quarter of 2016 and 2015

Overview

Net income for the Company's reportable segments is summarized as follows (in millions):

	First Quarter
	2016			2015			Change
Net income attributable to BHE shareholders:
PacifiCorp	$	165		$	134		$	31		23	%
MidAmerican Funding	73			95			(22		)	(23	)
NV Energy	21			44			(23		)	(52	)
Northern Powergrid	98			127			(29		)	(23	)
BHE Pipeline Group	109			112			(3		)	(3	)
BHE Transmission	48			43			5			12
BHE Renewables	12			—			12			*
HomeServices	1			(2		)	3			*
BHE and Other	(37		)	(84		)	47			56
Total net income attributable to BHE shareholders	$	490		$	469		$	21		4

*    Not meaningful

28

Net income attributable to BHE shareholders increased $21 million for the first quarter of 2016 compared to 2015 due to the following:

• PacifiCorp's net income increased due to higher margins of $51 million, partially offset by lower AFUDC of $5 million. Margins increased primarily due to lower average cost of natural gas, lower coal-fueled generation, higher retail customer load, higher retail rates and lower purchased electricity prices, partially offset by higher natural gas-fueled generation and lower wholesale electricity revenue from lower volumes and prices. Customer load increased 1.0% due to the impacts of weather on residential and commercial customer loads, an increase in the average number of residential and commercial customers primarily in Utah and higher residential customer usage in Oregon, partially offset by lower industrial customer usage across the service territory and lower residential customer usage in Utah.

• MidAmerican Funding's net income decreased due to a pre-tax gain of $13 million in 2015 on the sale of a generating facility lease, higher depreciation and amortization of $10 million due to wind-powered generation and other plant placed in-service, lower recognized production tax credits of $8 million, higher interest expense of $4 million primarily due to the issuance of first mortgage bonds in October 2015 and lower natural gas margins of $3 million due to warmer winter temperatures, partially offset by lower fossil-fueled generation maintenance of $4 million and higher electric margins of $3 million. Electric margins reflect lower energy costs, higher retail rates in Iowa and higher transmission revenue, partially offset by lower recoveries through bill riders, lower wholesale revenue and lower retail sales volumes.

• NV Energy's net income decreased due to higher operating expense of $28 million, higher depreciation and amortization of $3 million primarily due to higher plant in-service and lower electric margins of $2 million, partially offset by higher natural gas margins of $2 million. Operating expense increased due to benefits from changes in contingent liabilities in 2015 and planned maintenance and other generating costs.

• Northern Powergrid's net income decreased due to lower distribution revenues mainly reflecting the impact of the new price control period effective April 1, 2015 and the stronger United States dollar of $6 million.

• BHE Pipeline Group's net income decreased due to lower transportation revenue at Northern Natural Gas from lower volumes and rates due to mild temperatures, partially offset by lower operating expenses due to the timing of overhauls and pipeline integrity projects and lower interest expense from the early redemption in December 2015 of the 6.676% Senior Notes at Kern River.

• BHE Transmission's net income increased primarily due to additional assets placed in-service and lower operating expenses at AltaLink, partially offset by the stronger United States dollar of $4 million.

• BHE Renewables' net income increased due primarily to higher wind generation, a favorable change in the valuation of a power purchase agreement derivative and higher production tax credits of $9 million, partially offset by higher interest expense and lower capitalized interest at the Solar Star project and unfavorable movements in the Pinyon Pines interest rate swaps.

• HomeServices' net income increased largely due to a $2 million gain in 2016 from the acquisition of interests in equity method investments. Higher earnings at mortgage businesses from improved revenues were largely offset by lower earnings at brokerage businesses due to higher operating expenses.

• BHE and Other net loss decreased due primarily to favorable deferred state income tax benefits and an increase in federal income tax credits recognized on a consolidated basis.

29

Reportable Segment Results

Operating revenue and operating income for the Company's reportable segments are summarized as follows (in millions):

	First Quarter
	2016		2015		Change
Operating revenue:
PacifiCorp	$	1,252	$	1,250	$	2		—	%
MidAmerican Funding	626		727		(101		)	(14	)
NV Energy	615		706		(91		)	(13	)
Northern Powergrid	279		324		(45		)	(14	)
BHE Pipeline Group	315		332		(17		)	(5	)
BHE Transmission	158		125		33			26
BHE Renewables	139		124		15			12
HomeServices	491		448		43			10
BHE and Other	166		185		(19		)	(10	)
Total operating revenue	$	4,041	$	4,221	$	(180	)	(4	)

Operating income:
PacifiCorp	$	324		$	273		$	51		19	%
MidAmerican Funding	100			101			(1		)	(1	)
NV Energy	89			121			(32		)	(26	)
Northern Powergrid	158			193			(35		)	(18	)
BHE Pipeline Group	192			200			(8		)	(4	)
BHE Transmission	76			46			30			65
BHE Renewables	24			6			18			*
HomeServices	(1		)	(2		)	1			50
BHE and Other	(9		)	(8		)	(1		)	(13	)
Total operating income	$	953		$	930		$	23		2

*    Not meaningful

PacifiCorp

Operating revenue increased $2 million for 2016 compared to 2015 due to higher retail revenue of $45 million, substantially offset by lower wholesale and other revenue of $43 million. The increase in retail revenue was due to higher retail customer load of $23 million and higher retail rates of $22 million. Retail customer load increased 1.0% due to the impacts of weather on residential and commercial customer loads, an increase in the average number of residential and commercial customers primarily in Utah and higher residential customer usage in Oregon, partially offset by lower industrial customer usage across the service territory and lower residential customer usage in Utah. Wholesale and other revenue decreased due to lower wholesale volumes of $36 million and lower average wholesale prices of $7 million.

Operating income increased $51 million for 2016 compared to 2015 due to higher margins of $51 million. Margins increased due to lower energy costs of $49 million and higher operating revenue. Energy costs decreased due to lower average cost of natural gas, lower coal-fueled generation and lower purchased electricity prices, partially offset by higher natural gas-fueled generation.

30

MidAmerican Funding

Operating revenue decreased $101 million for 2016 compared to 2015 due to lower natural gas operating revenue of $69 million, lower electric operating revenue of $27 million and lower other operating revenue of $5 million. Natural gas operating revenue decreased due to a lower average per-unit cost of gas sold of $48 million, which is offset in cost of sales, and 10.2% lower retail sales volumes, primarily from warmer winter temperatures in 2016, and 4.4% lower wholesale volumes. Electric operating revenue decreased due to lower retail revenue of $16 million and lower wholesale and other revenue of $11 million. Retail revenue decreased $20 million from lower recoveries through bill riders, which are substantially offset by cost of sales, operating expense and production tax credits, and $7 million from the impact of warmer winter temperatures in 2016, partially offset by $10 million from higher electric rates in Iowa effective January 1, 2016. Electric retail customer load decreased 0.5% as the impact of warmer winter temperatures was largely offset by strong industrial growth. Electric wholesale and other revenue decreased primarily due to lower wholesale volumes of $18 million, partially offset by higher transmission revenue of $4 million related to Multi-Value Projects, which are expected to increase as projects are constructed over the next two years.

Operating income decreased $1 million for 2016 compared to 2015 due to lower natural gas operating income of $4 million and lower other operating income of $1 million, partially offset by higher electric operating income of $4 million. Natural gas operating income decreased due to the lower retail sales volumes. Electric operating income increased due to lower energy costs of $30 million from lower coal-fueled generation in part due to greater wind-powered generation and a lower price for purchased power, lower fossil-fueled generation maintenance of $4 million from planned outages in 2015 and lower electric distribution costs of $4 million, partially offset by the lower operating revenue and higher depreciation and amortization of $9 million due to wind generation and other plant placed in-service.

NV Energy

Operating revenue decreased $91 million for 2016 compared to 2015 due to lower electric operating revenue of $86 million and lower natural gas operating revenue of $3 million primarily due to lower energy rates partially offset by higher customer usage. Electric operating revenue decreased due to lower retail revenue of $82 million and lower wholesale and other revenue of $4 million primarily due to lower transmission revenue. Retail revenue decreased primarily due to $89 million from lower retail rates as a result of lower energy costs which are passed on to customers through deferred energy adjustment mechanisms, partially offset by $4 million from higher customer growth and $3 million of higher energy efficiency rate revenue, which is offset in operating expense. Electric retail customer load decreased 0.1% compared to 2015.

Operating income decreased $32 million for 2016 compared to 2015 due to higher operating expense of $28 million, related to benefits from changes in contingent liabilities in 2015 and planned maintenance and other generating costs, higher depreciation and amortization of $3 million, primarily due to higher plant in-service, and lower electric margins of $2 million, partially offset by higher natural gas margins of $2 million. The change in electric margins is due to lower electric operating revenue, partially offset by lower energy costs of $89 million. Energy costs decreased due to lower net deferred power costs of $70 million and a lower average cost of fuel for generation of $29 million, partially offset by higher purchased power costs of $10 million.

Northern Powergrid

Operating revenue decreased $45 million for 2016 compared to 2015 due to lower distribution revenue of $30 million and the stronger United States dollar of $16 million. Distribution revenue decreased due to lower tariff rates of $47 million mainly reflecting the impact of the new price control period effective April 1, 2015 and lower units distributed of $2 million, partially offset by the recovery of the December 2013 customer rebate of $11 million and favorable movements in regulatory provisions of $8 million. Operating income decreased $35 million for 2016 compared to 2015 primarily due to the lower distribution revenue and the stronger United States dollar of $9 million, partially offset by lower pension costs of $5 million.

BHE Pipeline Group

Operating revenue decreased $17 million for 2016 compared to 2015 due to lower transportation revenues at Northern Natural Gas from lower volumes and rates due to mild temperatures. Operating income decreased $8 million for 2016 compared to 2015 due to the lower transportation revenues, partially offset by lower operating expenses due to the timing of overhauls and pipeline integrity projects.

31

BHE Transmission

Operating revenue increased $33 million for 2016 compared to 2015 due to $50 million from additional assets placed in-service at AltaLink, partially offset by $17 million due to the stronger United States dollar. Operating income increased $30 million for 2016 compared to 2015 due to the higher operating revenue and lower operating expenses due to lower volume of third party transmission construction service and lower labor costs, partially offset by higher depreciation due to additional assets placed in-service and $8 million due to the stronger United States dollar.

BHE Renewables

Operating revenue increased $15 million for 2016 compared to 2015 due to an increase of $7 million as additional solar and wind capacity was placed in-service, a favorable change in the valuation of a power purchase agreement derivative of $9 million and higher wind generation at the Pinyon Pines projects of $6 million, partially offset by a $6 million decrease due to lower geothermal and natural gas generation.

Operating income increased $18 million for 2016 compared to 2015 due to the higher operating revenue and lower operating expense of $9 million, partially offset by higher depreciation and amortization of $6 million from additional solar and wind capacity placed in-service. Operating expense decreased due to the scope and timing of maintenance at certain geothermal plants and lower project acquisition costs, partially offset by additional solar and wind capacity placed in-service.

HomeServices

Operating revenue increased $43 million for 2016 compared to 2015 due to a 9.2% increase in closed brokerage units and a 4.2% increase in average home sales prices. The increase in operating revenue was due to an increase from existing businesses totaling $21 million and an increase in acquired businesses totaling $22 million. The increase in existing businesses reflects a 2.6% increase in closed brokerage units, a 5.0% increase in average home sales prices and $4 million of higher mortgage revenue. Operating income increased $1 million for 2016 compared to 2015 due to the higher revenues at existing and acquired businesses, partially offset by higher cost of sales and operating expense, primarily commission expense, at existing and acquired businesses.

BHE and Other

Operating revenue decreased $19 million for 2016 compared to 2015 due to lower natural gas prices and electricity volumes, partially offset by higher electricity prices, at MidAmerican Energy Services, LLC. Operating loss increased $1 million for 2016 compared to 2015 as lower margins of $7 million at MidAmerican Energy Services, LLC were largely offset by lower other operating expenses.

Consolidated Other Income and Expense Items

Interest Expense

Interest expense is summarized as follows (in millions):

	First Quarter
	2016		2015		Change
Subsidiary debt	$	349	$	341	$	8		2	%
BHE senior debt and other	102		103		(1		)	(1	)
BHE junior subordinated debentures	22		28		(6		)	(21	)
Total interest expense	$	473	$	472	$	1		—

Interest expense on subsidiary debt increased $8 million for 2016 compared to 2015 due to debt issuances at MidAmerican Funding and BHE Renewables, partially offset by scheduled maturities and principal payments and the impact of foreign currency exchange rate movements of $6 million.

Interest expense on BHE junior subordinated debentures decreased $6 million for 2016 compared to 2015 due to repayments totaling $500 million in March 2016, $250 million in December 2015 and $600 million in June 2015.

32

Capitalized Interest

Capitalized interest decreased $18 million for 2016 compared to 2015 due to lower construction work-in-progress balances at AltaLink, BHE Renewables and PacifiCorp.

Allowance for Equity Funds

Allowance for equity funds decreased $16 million for 2016 compared to 2015 due to lower construction work-in-progress balances at AltaLink and PacifiCorp.

Other, net

Other, net decreased $16 million for 2016 compared to 2015 primarily due to a $13 million gain at MidAmerican Funding on the sale of a generating facility lease in 2015 and unfavorable movements in the Pinyon Pines interest rate swaps of $5 million.

Income Tax Expense

Income tax expense decreased $49 million for 2016 compared to 2015 and the effective tax rate was 14% for 2016 and 22% for 2015. The effective tax rate decreased due to favorable deferred state income tax benefits and higher production tax credits recognized of $11 million, partially offset by the impacts of rate making of $5 million.

Production tax credits are recognized in earnings for interim periods based on the application of an estimated annual effective tax rate to pretax earnings. Federal renewable electricity production tax credits are earned as energy from qualifying wind-powered generating facilities is produced and sold and are based on a per-kilowatt hour rate pursuant to the applicable federal income tax law. Wind-powered generating facilities are eligible for the credits for 10 years from the date the qualifying generating facilities were placed in-service. Production tax credits recognized in 2016 were $68 million, or $11 million higher than 2015, while production tax credits earned in 2016 were $100 million, or $23 million higher than 2015. The difference between production tax credits recognized and earned of $32 million as of March 31, 2016, primarily at MidAmerican Energy, will be reflected in earnings over the remainder of 2016.

33

Liquidity and Capital Resources

Each of BHE's direct and indirect subsidiaries is organized as a legal entity separate and apart from BHE and its other subsidiaries. It should not be assumed that the assets of any subsidiary will be available to satisfy BHE's obligations or the obligations of its other subsidiaries. However, unrestricted cash or other assets that are available for distribution may, subject to applicable law, regulatory commitments and the terms of financing and ring-fencing arrangements for such parties, be advanced, loaned, paid as dividends or otherwise distributed or contributed to BHE or affiliates thereof. Refer to Note 17 of Notes to Consolidated Financial Statements in Item 8 of the Company's Annual Report on Form 10-K for the year ended December 31, 2015 for further discussion regarding the limitation of distributions from BHE's subsidiaries.

The Company's long-term debt may include provisions that allow BHE or its subsidiaries to redeem such debt in whole or in part at any time. These provisions generally include make-whole premiums.

As of March 31, 2016, the Company's total net liquidity was as follows (in millions):

							MidAmerican			NV		Northern
	BHE			PacifiCorp			Funding			Energy		Powergrid		AltaLink			Other			Total
Cash and cash equivalents	$	73		$	167		$	2		$	483	$	40	$	9		$	312		$	1,086
Credit facilities	2,000			1,200			609			650		215		865			953			6,492
Less:
Short-term debt	(805		)	—			(70		)	—		—		(460		)	(387		)	(1,722		)
Tax-exempt bond support and letters of credit	(11		)	(150		)	(190		)	—		—		(10		)	—			(361		)
Net credit facilities	1,184			1,050			349			650		215		395			566			4,409
Total net liquidity	$	1,257		$	1,217		$	351		$	1,133	$	255	$	404		$	878		$	5,495
Credit facilities:
Maturity dates	2017			2017, 2018			2016, 2018			2018		2020		2017, 2020			2016, 2018

Operating Activities

Net cash flows from operating activities for the three-month periods ended March 31, 2016 and 2015 were $1.4 billion and $1.1 billion, respectively. Improved operating results and other changes in working capital were partially offset by higher interest payments.

In December 2015, the Protecting Americans from Tax Hikes Act of 2015 ("PATH") was signed into law, extending bonus depreciation for qualifying property acquired and placed in-service before January 1, 2020 (bonus depreciation rates will be 50% in 2015-2017, 40% in 2018, and 30% in 2019), with an additional year for certain longer lived assets. Production tax credits were extended and phased-out for wind power and other forms of non-solar renewable energy projects that begin construction before the end of 2019. Production tax credits are maintained at full value through 2016, at 80% of value in 2017, at 60% of value in 2018, and 40% of value in 2019. Investment tax credits were extended and phased-down for solar projects that are under construction before the end of 2021 (investment tax credit rates are 30% through 2019, 26% in 2020 and 22% in 2021; they revert to the statutory rate of 10% thereafter). As a result of PATH, the Company's cash flows from operations are expected to benefit in 2016 and beyond due to bonus depreciation on qualifying assets placed in-service and production tax credits and investment tax credits earned on qualifying wind and solar projects, respectively.

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Investing Activities

Net cash flows from investing activities for the three-month periods ended March 31, 2016 and 2015 were $(1.3) billion and $(1.5) billion, respectively. The change was primarily due to lower capital expenditures of $399 million, partially offset by a $264 million tax equity investment in 2016.

Financing Activities

Net cash flows from financing activities for the three-month period ended March 31, 2016 was $(99) million. Uses of cash totaled $821 million and consisted mainly of repayment of BHE junior subordinated debentures of $500 million and repayments of subsidiary debt totaling $310 million. Sources of cash totaled $722 million related to net proceeds from short-term debt.

In April 2016, Sierra Pacific issued $400 million of its 2.60% General and Refunding Securities, Series U, due May 2026. The net proceeds will be used, together with cash on hand, to pay at maturity the $450 million principal amount of 6.00% General and Refunding Securities, Series M, maturing in May 2016.

Net cash flows from financing activities for the three-month period ended March 31, 2015 was $239 million. Sources of cash totaled $647 million and consisted of proceeds from subsidiary debt issuances of $484 million and net proceeds from short-term debt of $163 million. Uses of cash totaled $408 million and consisted mainly of repayments of subsidiary debt of $353 million and repurchases of common stock totaling $36 million.

Future Uses of Cash

The Company has available a variety of sources of liquidity and capital resources, both internal and external, including net cash flows from operating activities, public and private debt offerings, the issuance of commercial paper, the use of unsecured revolving credit facilities, the issuance of equity and other sources. These sources are expected to provide funds required for current operations, capital expenditures, acquisitions, investments, debt retirements and other capital requirements. The availability and terms under which BHE and each subsidiary has access to external financing depends on a variety of factors, including its credit ratings, investors' judgment of risk and conditions in the overall capital markets, including the condition of the utility industry and project finance markets, among other items.

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Capital Expenditures

The Company has significant future capital requirements. Capital expenditure needs are reviewed regularly by management and may change significantly as a result of these reviews, which may consider, among other factors, changes in environmental and other rules and regulations; impacts to customers' rates; outcomes of regulatory proceedings; changes in income tax laws; general business conditions; load projections; system reliability standards; the cost and efficiency of construction labor, equipment and materials; commodity prices; and the cost and availability of capital. Expenditures for certain assets may ultimately include acquisitions of existing assets.

The Company's historical and forecast capital expenditures, each of which exclude amounts for non-cash equity AFUDC and other non-cash items are as follows (in millions):

	Three-Month Periods				Annual
	Ended March 31,				Forecast
	2015		2016		2016
Capital expenditures by business:
PacifiCorp	$	208	$	201	$	795
MidAmerican Funding	244		332		1,145
NV Energy	115		146		476
Northern Powergrid	162		155		609
BHE Pipeline Group	46		30		276
BHE Transmission	265		112		491
BHE Renewables	382		45		557
HomeServices	3		4		25
BHE and Other	1		2		26
Total	$	1,426	$	1,027	$	4,400

Capital expenditures by type:
Wind generation	$	84	$	105	$	1,134
Solar generation	332		5		20
Electric transmission	341		115		506
Environmental	33		16		105
Other development projects	13		5		59
Electric distribution and other operating	623		781		2,576
Total	$	1,426	$	1,027	$	4,400

The Company's historical and forecast capital expenditures consisted mainly of the following:

•Wind generation includes the following:

◦ Construction of wind-powered generating facilities at MidAmerican Energy totaling $69 million and $45 million for the three-month periods ended March 31, 2016 and 2015, respectively. MidAmerican Energy anticipates costs for wind-powered generating facilities will total an additional $591 million for 2016. MidAmerican Energy is constructing 599 MW (nominal ratings) that are expected to be placed in-service in 2016, of which 48 MW (nominal ratings) had been placed in-service as of March 31, 2016.

◦ Construction of wind-powered generating facilities at BHE Renewables totaling $36 million and $39 million for the three-month periods ended March 31, 2016 and 2015, respectively. The Jumbo Road Project with a total capacity of 300 MW achieved commercial operation in April 2015. BHE Renewables anticipates costs for wind-powered generating facilities will total an additional $425 million for 2016. BHE Renewables is developing and constructing up to 472 MW of wind-powered generating facilities in Nebraska and Kansas.

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• Solar generation includes the following:

◦ Construction of the Topaz Project totaling $- million and $43 million for the three-month periods ended March 31, 2016 and 2015, respectively. 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.

◦ Construction of the Solar Star Projects totaling $5 million and $283 million for the three-month periods ended March 31, 2016 and 2015, respectively. 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.

• 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 245 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.

• Electric distribution and other operating includes ongoing distribution systems infrastructure needed at the Utilities and Northern Powergrid and investments in routine expenditures for transmission, generation and other infrastructure needed to serve existing and expected demand.

MidAmerican Energy Wind

In April 2016, MidAmerican Energy filed with the IUB an application for ratemaking principles related to the 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 filing, which is subject to IUB approval, establishes a cost cap of $3.6 billion, including AFUDC, and provides for a fixed rate of return on equity of 11.5% 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 filing proposes modifications to the revenue sharing mechanism currently in effect. The proposed sharing mechanism would be effective in 2018 and would 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 proposed change in revenue sharing, MidAmerican Energy would share 100% of the revenue in excess of this trigger with customers. Such revenue sharing would reduce coal and nuclear generation rate base, which is intended to mitigate future base rate increases. MidAmerican Energy has requested IUB approval by the end of the third quarter of 2016. If approved by the IUB, MidAmerican Energy expects to incur approximately $300 million of additional capital expenditures in 2016, which are not reflected in the current 2016 forecast.

Other Renewable Investments

The Company has invested in projects sponsored by third parties, commonly referred to as tax equity investments. Under the terms of these tax equity investments, the Company has entered into equity capital contribution agreements with the project sponsors that require contributions. The Company has made contributions of approximately $170 million in 2015, $264 million in the first three months of 2016 and expects to contribute $406 million for the remainder of 2016 pursuant to these equity capital contribution agreements as the various projects achieve commercial operation. Once a project achieves commercial operation, the Company will enter into a partnership agreement with the project sponsor that directs and allocates the operating profits and tax benefits generated by the project.

Contractual Obligations

As of March 31, 2016, there have been no material changes outside the normal course of business in contractual obligations from the information provided in Item 7 of the Company's Annual Report on Form 10-K for the year ended December 31, 2015 other than the 2016 debt issuances and the renewable tax equity investments previously discussed.

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Quad Cities Station Operating Status

Exelon Generation, the operator of Quad Cities Station of which MidAmerican Energy has a 25% ownership interest, has announced on May 6, 2016 its intention to shut down Quad Cities Station on June 1, 2018 if Illinois does not pass adequate legislation by May 31, 2016 or if Quad Cities Station does not clear the 2019-2020 PJM Interconnection, L.L.C. capacity auction, the results of which are expected to be available by May 24, 2016. MidAmerican Energy has expressed to Exelon Generation its desire for the continued operation of the facility through the end of its operating license in 2032. Actions by Exelon Generation to retire Quad Cities Station before the end of its operating license would require an evaluation of MidAmerican Energy's legal rights pursuant to the Quad Cities Station agreements with Exelon Generation. In addition, the carrying value and classification of assets and liabilities related to Quad Cities Station on MidAmerican Energy's balance sheets would need to be evaluated, and a determination made of the sufficiency of the nuclear decommissioning trust fund to fund decommissioning costs at an earlier retirement date. If the trust fund is determined to be deficient, MidAmerican Energy may be required to contribute additional assets to the trust fund or directly pay certain decommissioning costs.

Regulatory Matters

BHE's regulated subsidiaries and certain affiliates are subject to comprehensive regulation. The discussion below contains material developments to those matters disclosed in Item 1 of the Company's Annual Report on Form 10-K for the year ended December 31, 2015, and new regulatory matters occurring in 2016.

PacifiCorp

Utah

In March 2016, PacifiCorp filed its annual Energy Balancing Account ("EBA") with the UPSC requesting recovery of $19 million in deferred net power costs for the period January 1, 2015 through December 31, 2015. If approved by the UPSC, the new rates will be effective November 2016 on an interim basis until a final order is issued by the UPSC.

In March 2016, PacifiCorp filed its annual Renewable Energy Credit ("REC") balancing account application with the UPSC requesting recovery of $7 million for the period January 1, 2015 through December 31, 2015. If approved by the UPSC, the new rates will be effective June 2016.

Utah Senate Bill 115 ("SB 115"), Sustainable Transportation and Energy Plan, was signed into law in March 2016. The legislation establishes a five-year pilot program to provide up to $10 million annually of mandated funding for electric vehicle infrastructure and clean coal research, and authorizes funding at the commission’s discretion for solar development, utility-scale battery storage, and other innovative technology, economic development and air quality initiatives. SB 115 also authorizes the development of a renewable energy tariff for large customer loads. The legislation also allows PacifiCorp to change its regulatory accounting for energy efficiency services and programs from expense to capital, to be amortized over a ten-year period. The difference between amounts collected in rates for energy efficiency services and programs and the annual amount of cost amortization will result in a regulatory liability that may be used for depreciation of its coal-fired plants, as determined by the commission. Beginning June 1, 2016, the legislation also mandates full recovery of Utah's share of incremental fuel, purchased power and other variable supply costs through the EBA that are not fully in base rates rather than the prior recovery of 70%.

Oregon

In April 2016, PacifiCorp submitted its initial filing for the annual Transition Adjustment Mechanism filing in Oregon requesting an annual increase of $20 million, or an average price increase of 2%, based on forecasted net power costs and loads for calendar year 2017. Consistent with the passage of Oregon Senate Bill 1547-B ("SB 1547-B"), the filing includes the impact of expiring production tax credits, which account for $5 million of the requested increase. The filing will be updated for changes in contracts and market conditions in July and November 2016, before final rates become effective in January 2017.

Wyoming

In March 2016, PacifiCorp filed its annual Energy Cost Adjustment Mechanism ("ECAM") and Renewable Energy Credit and Sulfur Dioxide Revenue Adjustment Mechanism ("RRA") applications with the WPSC. The ECAM filing requests approval to recover $12 million in deferred net power costs for the period January 1, 2015 through December 31, 2015, and the RRA application requests approval to refund $1 million to customers. If approved by the WPSC, the ECAM and RRA rates will be effective May 2016 on an interim basis until a final order is issued by the WPSC.

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Washington

In December 2013, the WUTC approved an annual increase of $17 million, or an average price increase of 6%, effective December 2013 related to a general rate case filed in January 2013 requesting $37 million, or an average price increase of 12%. In January 2014, PacifiCorp filed a petition for judicial review of certain findings of the WUTC's December 2013 order. In April 2016, the Washington Court of Appeals issued its order in the appeal of the general rate case. The two issues before the court were the WUTC's decisions to: (1) re-price power purchase agreements with California and Oregon qualifying facilities at market prices; and (2) the cost of capital, including use of a hypothetical capital structure. The court affirmed the WUTC, deferring to the WUTC's discretion in ratemaking and concluding that it did not abuse that discretion. PacifiCorp is evaluating the next steps, including whether to seek reconsideration or further appeal to the Washington Supreme Court.

Idaho

In February 2016, PacifiCorp filed its annual ECAM application with the IPUC requesting recovery of $17 million, consisting primarily of $7 million for deferred net power costs, $6 million for the difference between REC revenues included in base rates and actual REC revenues and $4 million for a Lake Side 2 resource adder. In March 2016, the IPUC approved recovery of $17 million effective April 2016.

California

In March 2016, the CPUC approved PacifiCorp's application to recover a $1 million revenue requirement associated with drought-related fire hazard mitigation costs recorded in its catastrophic events memorandum account in 2014.

NV Energy (Nevada Power and Sierra Pacific)

In November 2014, one Nevada Power retail electric customer filed an application with the PUCN to purchase energy from a provider of a new electric resource and become a distribution only service customer, as allowed by Chapter 704B of the Nevada Revised Statutes. Chapter 704B allows retail electric customers with an average annual load of one MW or more to file a letter of intent and application with the PUCN to acquire electric energy and ancillary services from another energy supplier. The application was denied in June 2015 and the customer subsequently filed a petition for reconsideration. In July 2015, the PUCN approved a settlement between the customer and Nevada Power. In October 2015, the PUCN approved a separate green energy agreement between Nevada Power and the customer and tariff changes embedded in the settlement agreement. The customer withdrew its petition for reconsideration in November 2015.

In May 2015, three additional Nevada Power customers filed applications to purchase energy from a provider of a new electric resource and become a distribution only service customer. In December 2015, the PUCN granted the applications of the three customers subject to conditions, including paying an impact fee, on-going charges and receiving approval for specific alternative energy providers and terms.

In December 2015, the customers filed petitions for reconsideration. In January 2016, the PUCN granted reconsiderations and updated some of the terms, removing a limitation related to energy purchased indirectly from NV Energy. One of the applicants subsequently filed a petition for judicial review and a complaint for declaratory relief in state district court. There are no material applications pursuant to Chapter 704B pending before the PUCN in Nevada Power's and Sierra Pacific's respective service territories.

Net Metering

Nevada enacted Senate Bill 374 ("SB 374") on June 5, 2015. The legislation required the Nevada Utilities to prepare cost-of-service studies and propose new rules and rates for customers who install distributed, renewable generating resources. In July 2015, the Nevada Utilities made filings in compliance with SB 374 and the PUCN issued final orders December 23, 2015.

The final orders issued by the PUCN establish separate rate classes for customers who install distributed, renewable generating facilities. The establishment of separate rate classes recognizes the unique characteristics, costs and services received by these partial requirements customers. The PUCN also established new, cost-based rates or prices for these new customer classes, including increases in the basic service charge and related reductions in energy charges. Finally, the PUCN established a separate value for compensating customers who produce and deliver excess energy to the Nevada Utilities. The valuation will consider eleven factors, including alternatives available to the Nevada Utilities. The PUCN established a gradual, five-step process for transition over four years to the new, cost-based rates.

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In January 2016, the PUCN denied requests to stay the order issued December 23, 2015. The PUCN also voted to reopen the evidentiary proceeding to address the application of new net metering rules for customers who applied for net metering service before the issuance of the final order. In February 2016, the PUCN affirmed most of the provisions of the December 23, 2015 order and adopted a twelve-year transition plan for changing rates for net metering customers to cost-based rates for utility services and value-based pricing for excess energy. Subsequently, two solar industry interest groups filed petitions for judicial review of the PUCN order issued in February 2016. The petitions request that the court either modify the PUCN order or direct the PUCN to modify its decision in a manner that would maintain rates and rules of service applicable to net metering as existed prior to the December 23, 2015 order of the PUCN. In addition, a referendum has been filed in Nevada to modify the statutes applicable to net metering. This referendum was challenged in Nevada state court and the court determined the referendum was not consistent with the Nevada Constitution. The Nevada state court decision is on appeal to the Nevada Supreme Court.

ALP

General Tariff Applications

In November 2014, ALP filed a GTA asking the AUC to approve revenue requirements of C$811 million for 2015 and C$1.0 billion for 2016, primarily due to continued investment in capital projects as directed by the AESO.

In June 2015, ALP amended the GTA to propose additional transmission tariff relief measures for customers and modifications to its capital structure. The amended GTA includes timing benefits to customers by discontinuing (i) the use of construction work-in-progress in-rate base effective January 1, 2015, and refunding related amounts received as part of the 2011 to 2014 transmission tariffs and (ii) the collection in advance of future income taxes, effective January 1, 2016, and refunding amounts previously received as part of the transmission tariffs.

In October 2015, an update to this amended application was filed. The October 2015 update requested the AUC to approve an increase to 39% in ALP's common equity ratio resulting in revenue requirements of C$672 million for 2015 and C$704 million for 2016. In addition, the October 2015 update forecasted capital expenditures to be C$961 million for 2015 and C$538 million for 2016. ALP based its direct assign capital forecast, which comprises more than 80% of its total capital expenditures, on the long-range capital plan released by the AESO in January 2014, using its risk-adjusted capital forecasting model accepted by the AUC in its decision on ALP's previous general tariff application.

The oral hearing for the 2015-2016 GTA, which was amended and updated, took place December 2015 and the AUC is expected to issue its final decision in the second quarter of 2016. In addition, the AUC approved ALP's request to continue its 2015 interim transmission tariff decision to invoice the AESO C$61 million per month commencing January 1, 2016, until a final decision is issued for the 2015-2016 GTA.

In February 2016, ALP filed a GTA asking the AUC to approve its transmission tariff of C$853 million for 2017 and C$990 million for 2018. In March 2016, the AUC suspended the 2017-2018 GTA until the decision on the 2015-2016 GTA is issued.

The total tariff relief proposed in the 2015-2016 and 2017-2018 GTAs for ALP’s customers is approximately C$627 million over the 2015-2018 period.

2016 Generic Cost of Capital Proceeding

In April 2015, the AUC opened a new GCOC proceeding to set the deemed capital structure and generic returns for 2016 and 2017. ALP filed evidence in January 2016. ALP's external rate of return expert evidence proposes 9% to 10.5% return on equity, on a recommended equity component of 40%, compared to the placeholder return on equity of 8.3% on a 36% equity component. The fair return and equity thickness recommended reflect the concerns noted by rating agencies and other members of the financial community regarding the increased business risks of utilities in Alberta.

In March 2016, intervenors filed their expert evidence proposing a range of 7% to 7.5% return on equity, on a recommended equity component of 35% for AltaLink. The oral hearing is scheduled in May 2016 and a decision is not expected until later in 2016.

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Appeals of Recent AUC Decisions

In March 2015, the AUC issued its decision regarding cost of capital matters applicable to all electricity and natural gas utilities under its jurisdiction, including ALP. In its decision, which was retroactively applied to January 1, 2013, the AUC decreased the generic rate of return on common equity applicable to all utilities to 8.30% from the previously approved placeholder rate of 8.75% and decreased ALP's common equity ratio from 37% to 36% for the years 2013, 2014 and 2015. The approved common equity ratio and generic rate of return on common equity will remain in effect on an interim basis for 2016 and beyond, until changed by the AUC. ALP and other utilities had applied to the Alberta Court of Appeal for leave to appeal this decision; however, a decision not to proceed was made in the first quarter of 2016.

In November 2013, the AUC issued its Utility Asset Disposition ("UAD") decision in which it concluded, among other things, that in the case of the extraordinary retirement of an asset before it is fully depreciated, under or over recovery of capital investment on an extraordinary retirement should be borne by the utility and its shareholders. ALP and other utilities appealed the AUC's UAD decision to the Alberta Court of Appeal, which was dismissed in September 2015. In November 2015, ALP, Epcor and Enmax, filed a joint leave application to the Supreme Court of Canada for appeal of the Alberta Court of Appeal's UAD decision. The Supreme Court of Canada dismissed the appeal in April 2016.

In its November 2013 decision pertaining to ALP's 2013-2014 GTA, the AUC directed ALP to re-forecast the capital project expenditures for 2013 and 2014 Engineering, Procurement and Construction Management ("EPCM") services to reflect a two times labor multiplier and other approved mark-ups. While the AUC has not disallowed the new EPCM rates that ALP negotiated, there is a risk that, in a future direct assigned capital deferral account decision, the AUC may disallow a portion of the costs ALP has incurred for EPCM services in connection with capital projects executed under these relationship agreements. ALP has appealed this decision, which is scheduled to be heard in August 2016. ALP has requested approval of the capital project expenditures, including the new competitively bid EPCM rates, in its 2012-2013 direct assigned capital deferral account filing. ALP filed additional evidence supporting the new EPCM rates in 2015.

Environmental Laws and Regulations

The Company is subject to federal, state, local and foreign laws and regulations regarding air and water quality, renewable portfolio standards, emissions performance standards, climate change, coal combustion byproduct disposal, hazardous and solid waste disposal, protected species and other environmental matters that have the potential to impact its current and future operations. In addition to imposing continuing compliance obligations and capital expenditure requirements, these laws and regulations provide regulators with the authority to levy substantial penalties for noncompliance including fines, injunctive relief and other sanctions. These laws and regulations are administered by the EPA and various state, local and international agencies. All such laws and regulations are subject to a range of interpretation, which may ultimately be resolved by the courts. Environmental laws and regulations continue to evolve, and the Company is unable to predict the impact of the changing laws and regulations on its operations and consolidated financial results. The Company believes it is in material compliance with all applicable laws and regulations. Refer to "Liquidity and Capital Resources" for discussion of the Company's forecast environmental-related capital expenditures. The discussion below contains material developments to those matters disclosed in Item 1 of the Company's Annual Report on Form 10-K for the year ended December 31, 2015.

In March 2016, Oregon Senate Bill 1547-B, the Clean Electricity and Coal Transition Plan, was signed into law. SB 1547-B requires that coal-fueled resources are eliminated from Oregon's allocation of electricity by January 1, 2030, and increases the current renewable portfolio standards ("RPS") target from 25% in 2025 to 50% by 2040. SB 1547-B also implements new REC banking provisions, as well as the following interim RPS targets: 27% in 2025 through 2029, 35% in 2030 through 2034, 45% in 2035 through 2039, and 50% by 2040 and subsequent years.

New Accounting Pronouncements

For a discussion of new accounting pronouncements affecting the Company, refer to Note 2 of Notes to Consolidated Financial Statements in Part I, Item 1 of this Form 10-Q.

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Critical Accounting Estimates

Certain accounting measurements require management to make estimates and judgments concerning transactions that will be settled several years in the future. Amounts recognized on the Consolidated Financial Statements based on such estimates involve numerous assumptions subject to varying and potentially significant degrees of judgment and uncertainty and will likely change in the future as additional information becomes available. Estimates are used for, but not limited to, the accounting for the effects of certain types of regulation, derivatives, impairment of goodwill and long-lived assets, pension and other postretirement benefits, income taxes and revenue recognition - unbilled revenue. For additional discussion of the Company's critical accounting estimates, see Item 7 of the Company's Annual Report on Form 10-K for the year ended December 31, 2015. There have been no significant changes in the Company's assumptions regarding critical accounting estimates since December 31, 2015.

42

PacifiCorp and its subsidiaries

Consolidated Financial Section

43

PART I

Item 1. Financial Statements

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and Shareholders of

PacifiCorp

Portland, Oregon

We have reviewed the accompanying consolidated balance sheet of PacifiCorp and subsidiaries ("PacifiCorp") as of March 31, 2016, and the related consolidated statements of operations, changes in shareholders' equity and cash flows for the three-month periods ended March 31, 2016 and 2015. These interim financial statements are the responsibility of PacifiCorp's management.

We conducted our reviews in accordance with the standards of the Public Company Accounting Oversight Board (United States). A review of interim financial information consists principally of applying analytical procedures and making inquiries of persons responsible for financial and accounting matters. It is substantially less in scope than an audit conducted in accordance with the standards of the Public Company Accounting Oversight Board (United States), the objective of which is the expression of an opinion regarding the financial statements taken as a whole. Accordingly, we do not express such an opinion.

Based on our reviews, we are not aware of any material modifications that should be made to such consolidated interim financial statements for them to be in conformity with accounting principles generally accepted in the United States of America.

We have previously audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the consolidated balance sheet of PacifiCorp and subsidiaries as of December 31, 2015, and the related consolidated statements of operations, comprehensive income, changes in shareholders' equity, and cash flows for the year then ended (not presented herein); and in our report dated February 26, 2016, we expressed an unqualified opinion on those consolidated financial statements. In our opinion, the information set forth in the accompanying consolidated balance sheet as of December 31, 2015 is fairly stated, in all material respects, in relation to the consolidated balance sheet from which it has been derived.

/s/ Deloitte & Touche LLP

Portland, Oregon

May 6, 2016

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PACIFICORP AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS (Unaudited)

(Amounts in millions)

	As of
	March 31,		December 31,
	2016		2015
ASSETS
Current assets:
Cash and cash equivalents	$	167	$	12
Accounts receivable, net	604		740
Income taxes receivable	—		17
Inventories:
Materials and supplies	231		233
Fuel	216		192
Regulatory assets	93		102
Other current assets	78		81
Total current assets	1,389		1,377
Property, plant and equipment, net	19,036		19,026
Regulatory assets	1,580		1,583
Other assets	413		381
Total assets	$	22,418	$	22,367

The accompanying notes are an integral part of these consolidated financial statements.

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PACIFICORP AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS (Unaudited) (continued)

(Amounts in millions)

	As of
	March 31,			December 31,
	2016			2015
LIABILITIES AND SHAREHOLDERS' EQUITY
Current liabilities:
Accounts payable	$	414		$	473
Income taxes payable	67			—
Accrued employee expenses	99			70
Accrued interest	106			115
Accrued property and other taxes	88			62
Short-term debt	—			20
Current portion of long-term debt and capital lease obligations	65			68
Regulatory liabilities	37			34
Other current liabilities	234			229
Total current liabilities	1,110			1,071
Regulatory liabilities	948			938
Long-term debt and capital lease obligations	7,028			7,078
Deferred income taxes	4,738			4,750
Other long-term liabilities	1,026			1,027
Total liabilities	14,850			14,864
Commitments and contingencies (Note 7)
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	3,098			3,033
Accumulated other comprehensive loss, net	(11		)	(11		)
Total shareholders' equity	7,568			7,503
Total liabilities and shareholders' equity	$	22,418		$	22,367

The accompanying notes are an integral part of these consolidated financial statements.

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PACIFICORP AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF OPERATIONS (Unaudited)

(Amounts in millions)

	Three-Month Periods
	Ended March 31,
	2016			2015
Operating revenue	$	1,252		$	1,250
Operating costs and expenses:
Energy costs	427			476
Operations and maintenance	263			268
Depreciation and amortization	190			189
Taxes, other than income taxes	48			45
Total operating costs and expenses	928			978
Operating income	324			272
Other income (expense):
Interest expense	(95		)	(94		)
Allowance for borrowed funds	4			6
Allowance for equity funds	7			10
Other, net	3			3
Total other income (expense)	(81		)	(75		)
Income before income tax expense	243			197
Income tax expense	78			63
Net income	$	165		$	134

The accompanying notes are an integral part of these consolidated financial statements.

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PACIFICORP AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CHANGES IN SHAREHOLDERS' EQUITY (Unaudited)

(Amounts in millions)

										Accumulated
					Additional					Other			Total
	Preferred		Common		Paid-in		Retained			Comprehensive			Shareholders'
	Stock		Stock		Capital		Earnings			Loss, Net			Equity
Balance, December 31, 2014	$	2	$	—	$	4,479	$	3,288		$	(13	)	$	7,756
Net income	—		—		—		134			—			134
Common stock dividends declared	—		—		—		(450		)	—			(450		)
Balance, March 31, 2015	$	2	$	—	$	4,479	$	2,972		$	(13	)	$	7,440
Balance, December 31, 2015	$	2	$	—	$	4,479	$	3,033		$	(11	)	$	7,503
Net income	—		—		—		165			—			165
Common stock dividends declared	—		—		—		(100		)	—			(100		)
Balance, March 31, 2016	$	2	$	—	$	4,479	$	3,098		$	(11	)	$	7,568

The accompanying notes are an integral part of these consolidated financial statements.

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PACIFICORP AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited)

(Amounts in millions)

	Three-Month Periods
	Ended March 31,
	2016			2015
Cash flows from operating activities:
Net income	$	165		$	134
Adjustments to reconcile net income to net cash flows from operating activities:
Depreciation and amortization	190			189
Allowance for equity funds	(7		)	(10		)
Deferred income taxes and amortization of investment tax credits	(6		)	(10		)
Changes in regulatory assets and liabilities	29			21
Other, net	—			1
Changes in other operating assets and liabilities:
Accounts receivable and other assets	104			89
Derivative collateral, net	(3		)	(36		)
Inventories	(24		)	5
Income taxes	84			73
Accounts payable and other liabilities	—			26
Net cash flows from operating activities	532			482
Cash flows from investing activities:
Capital expenditures	(200		)	(208		)
Other, net	(2		)	(25		)
Net cash flows from investing activities	(202		)	(233		)
Cash flows from financing activities:
Repayments of long-term debt and capital lease obligations	(55		)	—
Net (repayments of) proceeds from short-term debt	(20		)	190
Common stock dividends	(100		)	(450		)
Net cash flows from financing activities	(175		)	(260		)
Net change in cash and cash equivalents	155			(11		)
Cash and cash equivalents at beginning of period	12			23
Cash and cash equivalents at end of period	$	167		$	12

The accompanying notes are an integral part of these consolidated financial statements.

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PACIFICORP AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

(1)    General

PacifiCorp, which includes PacifiCorp and its subsidiaries, is a United States regulated electric utility company serving retail customers, including residential, commercial, industrial, irrigation and other customers in portions of the states of Utah, Oregon, Wyoming, Washington, Idaho and California. PacifiCorp owns, or has interests in, a number of thermal, hydroelectric, wind-powered and geothermal generating facilities, as well as electric transmission and distribution assets. PacifiCorp also buys and sells electricity on the wholesale market with other utilities, energy marketing companies, financial institutions and other market participants. PacifiCorp is subject to comprehensive state and federal regulation. PacifiCorp's subsidiaries support its electric utility operations by providing coal mining services. PacifiCorp is an indirect subsidiary of Berkshire Hathaway Energy Company ("BHE"), a holding company based in Des Moines, Iowa that owns subsidiaries principally engaged in energy businesses. BHE is a consolidated subsidiary of Berkshire Hathaway Inc. ("Berkshire Hathaway").

The unaudited Consolidated Financial Statements have been prepared in accordance with accounting principles generally accepted in the United States of America ("GAAP") for interim financial information and the United States Securities and Exchange Commission's rules and regulations for Form 10-Q and Article 10 of Regulation S-X. Accordingly, they do not include all of the disclosures required by GAAP for annual financial statements. Management believes the unaudited Consolidated Financial Statements contain all adjustments (consisting only of normal recurring adjustments) considered necessary for the fair presentation of the unaudited Consolidated Financial Statements as of March 31, 2016 and for the three-month periods ended March 31, 2016 and 2015. The Consolidated Statements of Comprehensive Income have been omitted as net income equals comprehensive income for the three-month periods ended March 31, 2016 and 2015. The results of operations for the three-month period ended March 31, 2016 are not necessarily indicative of the results to be expected for the full year.

The preparation of the unaudited Consolidated Financial Statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities at the date of the unaudited Consolidated Financial Statements and the reported amounts of revenue and expenses during the period. Actual results may differ from the estimates used in preparing the unaudited Consolidated Financial Statements. Note 2 of Notes to Consolidated Financial Statements included in PacifiCorp's Annual Report on Form 10-K for the year ended December 31, 2015 describes the most significant accounting policies used in the preparation of the unaudited Consolidated Financial Statements. There have been no significant changes in PacifiCorp's assumptions regarding significant accounting estimates and policies during the three-month period ended March 31, 2016.

(2)    New Accounting Pronouncements

In February 2016, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") No. 2016-02, which creates FASB Accounting Standards Codification ("ASC") Topic 842, "Leases" and supersedes Topic 840 "Leases." This guidance increases transparency and comparability among entities by recording lease assets and lease liabilities on the balance sheet and disclosing key information about leasing arrangements. A lessee should recognize in the balance sheet a liability to make lease payments (the lease liability) and a right-of-use asset representing its right to use the underlying asset for the lease term. The recognition, measurement, and presentation of expenses and cash flows arising from a lease by a lessee have not significantly changed from previous guidance. This guidance is effective for interim and annual reporting periods beginning after December 15, 2018, with early adoption permitted, and is required to be adopted using a modified retrospective approach. PacifiCorp is currently evaluating the impact of adopting this guidance on its Consolidated Financial Statements and disclosures included within Notes to Consolidated Financial Statements.

In January 2016, the FASB issued ASU No. 2016-01, which amends FASB ASC Subtopic 825-10, "Financial Instruments - Overall." The amendments in this guidance address certain aspects of recognition, measurement, presentation and disclosure of financial instruments including a requirement that all investments in equity securities that do not qualify for equity method accounting or result in consolidation of the investee be measured at fair value with changes in fair value recognized in net income. This guidance is effective for interim and annual reporting periods beginning after December 15, 2017, with early adoption not permitted, and is required to be adopted prospectively by means of a cumulative-effect adjustment to the balance sheet as of the beginning of the fiscal year of adoption. PacifiCorp is currently evaluating the impact of adopting this guidance on its Consolidated Financial Statements and disclosures included within Notes to Consolidated Financial Statements.

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In May 2014, the FASB issued ASU No. 2014-09, which creates FASB ASC Topic 606, "Revenue from Contracts with Customers" and supersedes ASC Topic 605, "Revenue Recognition." The guidance replaces industry-specific guidance and establishes a single five-step model to identify and recognize revenue. The core principle of the guidance is that an entity should recognize revenue upon transfer of control of promised goods or services to customers in an amount that reflects the consideration to which an entity expects to be entitled in exchange for those goods or services. Additionally, the guidance requires the entity to disclose further quantitative and qualitative information regarding the nature and amount of revenues arising from contracts with customers, as well as other information about the significant judgments and estimates used in recognizing revenues from contracts with customers. In August 2015, the FASB issued ASU No. 2015-14, which defers the effective date of ASU No. 2014-09 one year to interim and annual reporting periods beginning after December 15, 2017. This guidance may be adopted retrospectively or under a modified retrospective method where the cumulative effect is recognized at the date of initial application. PacifiCorp is currently evaluating the impact of adopting this guidance on its Consolidated Financial Statements and disclosures included within Notes to Consolidated Financial Statements.

(3)    Property, Plant and Equipment, Net

Property, plant and equipment, net consists of the following (in millions):

		As of
		March 31,			December 31,
	Depreciable Life	2016			2015
Property, plant and equipment in-service	5-75 years	$	26,822		$	26,757
Accumulated depreciation and amortization		(8,485		)	(8,360		)
Net property, plant and equipment in-service		18,337			18,397
Construction work-in-progress		699			629
Total property, plant and equipment, net		$	19,036		$	19,026

(4)    Employee Benefit Plans

Net periodic benefit cost for the pension and other postretirement benefit plans included the following components (in millions):

	Three-Month Periods
	Ended March 31,
	2016			2015
Pension:
Service cost	$	1		$	1
Interest cost	14			13
Expected return on plan assets	(19		)	(19		)
Net amortization	8			10
Net periodic benefit cost	$	4		$	5
Other postretirement:
Service cost	$	1		$	1
Interest cost	4			4
Expected return on plan assets	(6		)	(6		)
Net amortization	(1		)	(1		)
Net periodic benefit credit	$	(2	)	$	(2	)

Employer contributions to the pension and other postretirement benefit plans are expected to be $4 million and $- million, respectively, during 2016. As of March 31, 2016, $1 million and $- million of contributions had been made to the pension and other postretirement benefit plans, respectively.

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(5)    Risk Management and Hedging Activities

PacifiCorp is exposed to the impact of market fluctuations in commodity prices and interest rates. PacifiCorp is principally exposed to electricity, natural gas, coal and fuel oil commodity price risk as it has an obligation to serve retail customer load in its regulated service territories. PacifiCorp's load and generating facilities represent substantial underlying commodity positions. Exposures to commodity prices consist mainly of variations in the price of fuel required to generate electricity and wholesale electricity that is purchased and sold. Commodity prices are subject to wide price swings as supply and demand are impacted by, among many other unpredictable items, weather, market liquidity, generating facility availability, customer usage, storage, and transmission and transportation constraints. Interest rate risk exists on variable-rate debt and future debt issuances. PacifiCorp does not engage in a material amount of proprietary trading activities.

PacifiCorp has established a risk management process that is designed to identify, assess, manage, mitigate, monitor and report each of the various types of risk involved in its business. To mitigate a portion of its commodity price risk, PacifiCorp uses commodity derivative contracts, which may include forwards, options, swaps and other agreements, to effectively secure future supply or sell future production generally at fixed prices. PacifiCorp manages its interest rate risk by limiting its exposure to variable interest rates primarily through the issuance of fixed-rate long-term debt and by monitoring market changes in interest rates. Additionally, PacifiCorp may from time to time enter into interest rate derivative contracts, such as interest rate swaps or locks, to mitigate PacifiCorp's exposure to interest rate risk. No interest rate derivatives were in place during the periods presented. PacifiCorp does not hedge all of its commodity price and interest rate risks, thereby exposing the unhedged portion to changes in market prices.

There have been no significant changes in PacifiCorp's accounting policies related to derivatives. Refer to Note 6 for additional information on derivative contracts.

The following table, which reflects master netting arrangements and excludes contracts that have been designated as normal under the normal purchases or normal sales exception afforded by GAAP, summarizes the fair value of PacifiCorp's derivative contracts, on a gross basis, and reconciles those amounts to the amounts presented on a net basis on the Consolidated Balance Sheets (in millions):

	Other					Other			Other
	Current			Other		Current			Long-term
	Assets			Assets		Liabilities			Liabilities			Total
As of March 31, 2016
Not designated as hedging contracts(1):
Commodity assets	$	5		$	—	$	2		$	—		$	7
Commodity liabilities	(1		)	—		(65		)	(89		)	(155		)
Total	4			—		(63		)	(89		)	(148		)
Total derivatives	4			—		(63		)	(89		)	(148		)
Cash collateral receivable	—			—		19			59			78
Total derivatives - net basis	$	4		$	—	$	(44	)	$	(30	)	$	(70	)
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 March 31, 2016 and December 31, 2015, a regulatory asset of $144 million and $133 million, respectively, was recorded related to the net derivative liability of $148 million and $136 million, respectively.

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Not Designated as Hedging Contracts

The following table reconciles the beginning and ending balances of PacifiCorp's net regulatory assets and summarizes the pre-tax gains and losses on commodity derivative contracts recognized in net regulatory assets, as well as amounts reclassified to earnings (in millions):

	Three-Month Periods
	Ended March 31,
	2016			2015
Beginning balance	$	133		$	85
Changes in fair value recognized in net regulatory assets	26			48
Net gains reclassified to operating revenue	8			25
Net losses reclassified to energy costs	(23		)	(28		)
Ending balance	$	144		$	130

Derivative Contract Volumes

The following table summarizes the net notional amounts of outstanding commodity derivative contracts with fixed price terms that comprise the mark-to-market values as of (in millions):

	Unit of	March 31,	December 31,
	Measure	2016	2015
Electricity purchases	Megawatt hours	2	1
Natural gas purchases	Decatherms	107	111
Fuel oil purchases	Gallons	9	11

Credit Risk

PacifiCorp is exposed to counterparty credit risk associated with wholesale energy supply and marketing activities with other utilities, energy marketing companies, financial institutions and other market participants. Credit risk may be concentrated to the extent PacifiCorp's counterparties have similar economic, industry or other characteristics and due to direct or indirect relationships among the counterparties. Before entering into a transaction, PacifiCorp analyzes the financial condition of each significant wholesale counterparty, establishes limits on the amount of unsecured credit to be extended to each counterparty and evaluates the appropriateness of unsecured credit limits on an ongoing basis. To further mitigate wholesale counterparty credit risk, PacifiCorp enters into netting and collateral arrangements that may include margining and cross-product netting agreements and obtains third-party guarantees, letters of credit and cash deposits. If required, PacifiCorp exercises rights under these arrangements, including calling on the counterparty's credit support arrangement.

Collateral and Contingent Features

In accordance with industry practice, certain wholesale derivative contracts contain credit support provisions that in part base certain collateral requirements on credit ratings for senior unsecured debt as reported by one or more of the three recognized credit rating agencies. These derivative contracts may either specifically provide bilateral rights to demand cash or other security if credit exposures on a net basis exceed specified rating-dependent threshold levels ("credit-risk-related contingent features") or provide the right for counterparties to demand "adequate assurance," or in some cases terminate the contract, in the event of a material adverse change in PacifiCorp's creditworthiness. These rights can vary by contract and by counterparty. As of March 31, 2016, PacifiCorp's credit ratings from the three recognized credit rating agencies were investment grade.

The aggregate fair value of PacifiCorp's derivative contracts in liability positions with specific credit-risk-related contingent features totaled $149 million and $142 million as of March 31, 2016 and December 31, 2015, respectively, for which PacifiCorp had posted collateral of $78 million and $75 million, respectively, in the form of cash deposits. If all credit-risk-related contingent features for derivative contracts in liability positions had been triggered as of March 31, 2016 and December 31, 2015, PacifiCorp would have been required to post $68 million and $64 million, respectively, of additional collateral. PacifiCorp's collateral requirements could fluctuate considerably due to market price volatility, changes in credit ratings, changes in legislation or regulation, or other factors.

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(6)    Fair Value Measurements

The carrying value of PacifiCorp's cash, certain cash equivalents, receivables, payables, accrued liabilities and short-term borrowings approximates fair value because of the short-term maturity of these instruments. PacifiCorp has various financial assets and liabilities that are measured at fair value on the Consolidated Financial Statements using inputs from the three levels of the fair value hierarchy. A financial asset or liability classification within the hierarchy is determined based on the lowest level input that is significant to the fair value measurement. The three levels are as follows:

• 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.

The following table presents PacifiCorp's assets and liabilities recognized on the Consolidated Balance Sheets and measured at fair value on a recurring basis (in millions):

	Input Levels for Fair Value Measurements
	Level 1		Level 2			Level 3		Other(1)			Total
As of March 31, 2016
Assets:
Commodity derivatives	$	—	$	6		$	1	$	(3	)	$	4
Money market mutual funds(2)	178		—			—		—			178
Investment funds	15		—			—		—			15
	$	193	$	6		$	1	$	(3	)	$	197
Liabilities - Commodity derivatives	$	—	$	(155	)	$	—	$	81		$	(74	)
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 $78 million and $75 million as of March 31, 2016 and December 31, 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.

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Derivative contracts are recorded on the Consolidated Balance Sheets as either assets or liabilities and are stated at estimated fair value unless they are designated as normal purchases or normal sales and qualify for the exception afforded by GAAP. When available, the fair value of derivative contracts is estimated using unadjusted quoted prices for identical contracts in the market in which PacifiCorp transacts. When quoted prices for identical contracts are not available, PacifiCorp uses forward price curves. Forward price curves represent PacifiCorp's estimates of the prices at which a buyer or seller could contract today for delivery or settlement at future dates. PacifiCorp bases its forward price curves upon market price quotations, when available, or internally developed and commercial models, with internal and external fundamental data inputs. Market price quotations are obtained from independent energy brokers, exchanges, direct communication with market participants and actual transactions executed by PacifiCorp. Market price quotations for certain major electricity and natural gas trading hubs are generally readily obtainable for the first six years; therefore, PacifiCorp's forward price curves for those locations and periods reflect observable market quotes. Market price quotations for other electricity and natural gas trading hubs are not as readily obtainable for the first six years. Given that limited market data exists for these contracts, as well as for those contracts that are not actively traded, PacifiCorp uses forward price curves derived from internal models based on perceived pricing relationships to major trading hubs that are based on unobservable inputs. The estimated fair value of these derivative contracts is a function of underlying forward commodity prices, interest rates, currency rates, related volatility, counterparty creditworthiness and duration of contracts. Refer to Note 5 for further discussion regarding PacifiCorp's risk management and hedging activities.

PacifiCorp's investments in money market mutual funds and investment funds are stated at fair value and are primarily accounted for as available-for-sale securities. When available, PacifiCorp uses a readily observable quoted market price or net asset value of an identical security in an active market is used to record the fair value. In the absence of a quoted market price or net asset value of an identical security, the fair value is determined using pricing models or net asset values based on observable market inputs and quoted market prices of securities with similar characteristics.

PacifiCorp's long-term debt is carried at cost on the Consolidated Balance Sheets. The fair value of PacifiCorp's long-term debt is a Level 2 fair value measurement and has been estimated based upon quoted market prices, where available, or at the present value of future cash flows discounted at rates consistent with comparable maturities with similar credit risks. The carrying value of PacifiCorp's variable-rate long-term debt approximates fair value because of the frequent repricing of these instruments at market rates. The following table presents the carrying value and estimated fair value of PacifiCorp's long-term debt (in millions):

	As of March 31, 2016				As of December 31, 2015
	Carrying		Fair		Carrying		Fair
	Value		Value		Value		Value
Long-term debt	$	7,061	$	8,437	$	7,114	$	8,210

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(7)    Commitments and Contingencies

Legal Matters

PacifiCorp is party to a variety of legal actions arising out of the normal course of business. Plaintiffs occasionally seek punitive or exemplary damages. PacifiCorp does not believe that such normal and routine litigation will have a material impact on its consolidated financial results. PacifiCorp is also involved in other kinds of legal actions, some of which assert or may assert claims or seek to impose fines, penalties and other costs in substantial amounts and are described below.

USA Power

In October 2005, prior to BHE's ownership of PacifiCorp, PacifiCorp was added as a defendant to a lawsuit originally filed in February 2005 in the Third District Court of Salt Lake County, Utah ("Third District Court") by USA Power, LLC, USA Power Partners, LLC and Spring Canyon Energy, LLC (collectively, the "Plaintiff"). The Plaintiff's complaint alleged that PacifiCorp misappropriated confidential proprietary information in violation of Utah's Uniform Trade Secrets Act and accused PacifiCorp of breach of contract and related claims in regard to the Plaintiff's 2002 and 2003 proposals to build a natural gas-fueled generating facility in Juab County, Utah. In October 2007, the Third District Court granted PacifiCorp's motion for summary judgment on all counts and dismissed the Plaintiff's claims in their entirety. In a May 2010 ruling on the Plaintiff's petition for reconsideration, the Utah Supreme Court reversed summary judgment and remanded the case back to the Third District Court for further consideration. In May 2012, a jury awarded damages to the Plaintiff for breach of contract and misappropriation of a trade secret in the amounts of $18 million for actual damages and $113 million for unjust enrichment. After considering various motions filed by the parties to expand or limit damages, interest and attorney's fees, in May 2013, the court entered a final judgment against PacifiCorp in the amount of $115 million, which includes the $113 million of aggregate damages previously awarded and amounts awarded for the Plaintiff's attorneys' fees. The final judgment also ordered that postjudgment interest accrue beginning as of the date of the April 2013 initial judgment. In May 2013, PacifiCorp posted a surety bond issued by a subsidiary of Berkshire Hathaway to secure its estimated obligation. PacifiCorp strongly disagrees with the jury's verdict and is vigorously pursuing all appellate measures. Both PacifiCorp and the Plaintiff filed appeals with the Utah Supreme Court. Briefing before the Utah Supreme Court is complete and oral arguments were heard in September 2015. As of March 31, 2016, PacifiCorp had accrued $122 million for the final judgment and postjudgment interest, and believes the likelihood of any additional material loss is remote; however, any additional awards against PacifiCorp could also have a material effect on the consolidated financial results. Any payment of damages will be at the end of the appeals process.

Sanpete County, Utah Rangeland Fire

In June 2012, a major rangeland fire occurred in Sanpete County, Utah. Certain parties allege that contact between two of PacifiCorp's transmission lines may have triggered a ground fault that led to the fire. PacifiCorp has engaged experts to review the cause and origin of the fire, as well as to assess the damages. PacifiCorp has accrued its best estimate of the potential loss and expected insurance recovery. PacifiCorp believes it is reasonably possible it may incur additional loss beyond the amount accrued, but does not believe the potential additional loss will have a material impact on its consolidated financial results.

Environmental Laws and Regulations

PacifiCorp is subject to federal, state and local laws and regulations regarding air and water quality, renewable portfolio standards, emissions performance standards, climate change, coal combustion byproduct disposal, hazardous and solid waste disposal, protected species and other environmental matters that have the potential to impact PacifiCorp's current and future operations. PacifiCorp believes it is in material compliance with all applicable laws and regulations.

Hydroelectric Relicensing

PacifiCorp's Klamath hydroelectric system is currently operating under annual licenses with the Federal Energy Regulatory Commission ("FERC"). In February 2010, PacifiCorp, the United States Department of the Interior, the United States Department of Commerce, the state of California, the state of Oregon and various other governmental and non-governmental settlement parties signed the Klamath Hydroelectric Settlement Agreement ("KHSA"). Among other things, the KHSA provided that the United States Department of the Interior would conduct scientific and engineering studies to assess whether removal of the Klamath hydroelectric system's mainstem dams was in the public interest and would advance restoration of the Klamath Basin's salmonid fisheries. If it was determined that dam removal should proceed, dam removal would have begun no earlier than 2020.

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Under the KHSA, PacifiCorp and its customers were protected from uncapped dam removal costs and liabilities. For dam removal to occur, federal legislation consistent with the KHSA was required to provide, among other things, protection for PacifiCorp from all liabilities associated with dam removal activities. As of December 31, 2015, no federal legislation had been enacted, and several parties to the KHSA initiated a dispute resolution process.

In February 2016, the principal parties to the KHSA (PacifiCorp, the states of California and Oregon and the United States Departments of the Interior and Commerce) executed an agreement in principle committing to explore potential amendment of the KHSA to facilitate removal of the Klamath dams through a FERC process without the need for federal legislation. Since that time, PacifiCorp, the states of California and Oregon, and the United States Departments of the Interior and Commerce have negotiated an amendment to the KHSA that was signed on April 6, 2016. Under the amended KHSA, PacifiCorp will file an application with the FERC to transfer the license for the four mainstem Klamath River hydroelectric generating facilities to a newly formed private entity, the Klamath River Renewal Corporation ("KRRC"). The KRRC will file an application to surrender the license and decommission the facilities with the FERC.

The amended KHSA provides PacifiCorp with liability protections comparable to the KHSA. The amended KHSA also limits PacifiCorp's contribution to facilities removal costs to no more than $200 million, of which up to $184 million would be collected from PacifiCorp's Oregon customers with the remainder to be collected from PacifiCorp's California customers. Additional funding of up to $250 million for facilities removal costs is to be provided by the state of California. California voters approved a water bond measure in November 2014 from which the state of California's contribution toward facilities removal costs will be drawn. If facilities removal costs exceed the combined funding that will be available from PacifiCorp's Oregon and California customers and the state of California, sufficient funds would need to be provided by the KRRC or an entity other than PacifiCorp in order for facilities removal to proceed.

If certain conditions in the amended KHSA are not satisfied and the license does not transfer to the KRRC, PacifiCorp will resume relicensing with the FERC.

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Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations

The following is management's discussion and analysis of certain significant factors that have affected the consolidated financial condition and results of operations of PacifiCorp during the periods included herein. Explanations include management's best estimate of the impact of weather, customer growth and other factors. This discussion should be read in conjunction with PacifiCorp's historical unaudited Consolidated Financial Statements and Notes to Consolidated Financial Statements in Part I, Item 1 of this Form 10‑Q. PacifiCorp's actual results in the future could differ significantly from the historical results.

Results of Operations for the First Quarter of 2016 and 2015

Overview

Net income for the first quarter of 2016 was $165 million, an increase of $31 million, or 23%, compared to 2015. Net income increased due to higher margins of $51 million, partially offset by lower AFUDC of $5 million. Margins increased primarily due to lower average cost of natural gas, lower coal-fueled generation, higher retail customer load, higher retail rates and lower purchased electricity prices, partially offset by higher natural gas-fueled generation and lower wholesale electricity revenue from lower volumes and prices. Retail customer load increased 1.0% due to the impacts of weather on residential and commercial customer loads, an increase in the average number of residential and commercial customers primarily in Utah and higher residential customer usage in Oregon, partially offset by lower industrial customer usage across the service territory and lower residential customer usage in Utah. Energy generated decreased 3% for the first quarter of 2016 compared to 2015 due to lower coal-fueled generation, partially offset by higher natural gas-fueled, hydroelectric and wind-powered generation. Wholesale electricity sales volumes decreased 29% and purchased electricity volumes decreased 9%.

Operating revenue and energy costs are the key drivers of PacifiCorp's results of operations as they encompass retail and wholesale electricity revenue and the direct costs associated with providing electricity to customers. PacifiCorp believes that a discussion of gross margin, representing operating revenue less energy costs, is therefore meaningful.

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A comparison of PacifiCorp's key operating results is as follows:

	First Quarter
	2016		2015		Change
Gross margin (in millions):
Operating revenue	$	1,252	$	1,250	$	2		—	%
Energy costs	427		476		(49		)	(10	)
Gross margin	$	825	$	774	$	51		7
Sales (GWh):
Residential	4,260		3,993		267			7	%
Commercial	4,091		4,030		61			2
Industrial and irrigation	4,822		5,037		(215		)	(4	)
Other	121		104		17			16
Total retail	13,294		13,164		130			1
Wholesale	1,894		2,654		(760		)	(29	)
Total sales	15,188		15,818		(630		)	(4	)
Average number of retail customers
(in thousands)	1,833		1,800		33			2	%
Average revenue per MWh:
Retail	$	87.99	$	85.47	$	2.52		3	%
Wholesale	$	24.53	$	33.81	$	(9.28	)	(27	)%
Sources of energy (GWh)(1):
Coal	8,732		10,352		(1,620		)	(16	)%
Natural gas	2,326		1,674		652			39
Hydroelectric(2)	1,344		1,024		320			31
Wind and other(2)	1,009		800		209			26
Total energy generated	13,411		13,850		(439		)	(3	)
Energy purchased	2,826		3,121		(295		)	(9	)
Total	16,237		16,971		(734		)	(4	)
Average cost of energy per MWh:
Energy generated(3)	$	17.89	$	19.72	$	(1.83	)	(9	)%
Energy purchased	$	48.49	$	47.37	$	1.12		2	%

(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.

59

Gross margin increased $51 million, or 7%, for the first quarter of 2016 compared to 2015 primarily due to:

• $49 million of lower natural gas costs due to lower average unit costs;

• $31 million of lower coal costs primarily due to decreased generation, including the idling of the Carbon Facility in April 2015;

• $23 million of higher retail revenues from a 1.0% increase in retail customer load due to the impacts of weather on residential and commercial customer loads, an increase in the average number of residential and commercial customers primarily in Utah and higher residential customer usage in Oregon, partially offset by lower industrial customer usage across the service territory and lower residential customer usage in Utah;

• $22 million of increases mainly from higher retail rates; and

• $11 million of lower purchased electricity primarily due to lower average market prices.

The increases above were partially offset by:

• $47 million of higher natural gas costs due to increased generation, primarily as a result of increased availability; and

• $43 million of lower wholesale revenue due to reduced volumes and lower average wholesale prices.

Operations and maintenance decreased $5 million, or 2%, for the first quarter of 2016 compared to 2015 primarily due to insurance recoveries expected from a prior period claim and lower labor and benefit costs.

Taxes, other than income taxes increased $3 million, or 7%, for the first quarter of 2016 compared to 2015 due to higher plant in-service and higher assessed property values.

Allowance for borrowed and equity funds decreased $5 million, or 31%, for the first quarter of 2016 compared to 2015 primarily due to lower qualified construction work-in-progress balances.

Income tax expense increased $15 million, or 24%, for the first quarter of 2016 compared to 2015 and the effective tax rate was 32% for 2016 and 2015. The increase in income tax expense was primarily due to higher pre-tax book income, partially offset by higher production tax credits associated with PacifiCorp's wind-powered generating facilities.

Liquidity and Capital Resources

As of March 31, 2016, PacifiCorp's total net liquidity was as follows (in millions):

Cash and cash equivalents	$	167
Credit facilities	1,200
Less:
Short-term debt	—
Tax-exempt bond support and letters of credit	(150		)
Net credit facilities	1,050
Total net liquidity	$	1,217
Credit facilities:
Maturity dates	2017, 2018

60

Operating Activities

Net cash flows from operating activities for the three-month periods ended March 31, 2016 and 2015 were $532 million and $482 million, respectively. The change was primarily due to higher receipts from retail customers, lower cash collateral posted for derivative contracts and lower purchased electricity payments, partially offset by lower receipts from wholesale electricity sales.

In December 2015, the Protecting Americans from Tax Hikes Act of 2015 ("PATH") was signed into law, extending bonus depreciation for qualifying property acquired and placed in-service before January 1, 2020 (bonus depreciation rates will be 50% in 2015-2017, 40% in 2018, and 30% in 2019), with an additional year for certain longer lived assets. As a result of PATH, PacifiCorp's cash flows from operations are expected to benefit in 2016 and beyond due to bonus depreciation on qualifying assets placed in-service.

Investing Activities

Net cash flows from investing activities for the three-month periods ended March 31, 2016 and 2015 were $(202) million and $(233) million, respectively. The change was related to a prior year service territory acquisition and lower capital expenditures of $8 million. Refer to "Future Uses of Cash" for discussion of capital expenditures.

Financing Activities

Net cash flows from financing activities for the three-month period ended March 31, 2016 was $(175) million. Uses of cash consisted substantially of $100 million for common stock dividends paid to PPW Holdings LLC, $54 million for the repayment of long-term debt and $20 million for the repayment of short-term debt.

Net cash flows from financing activities for the three-month period ended March 31, 2015 was $(260) million. Uses of cash consisted of $450 million for common stock dividends paid to PPW Holdings LLC. Sources of cash consisted of $190 million of net proceeds from short-term debt.

Short-term Debt

Regulatory authorities limit PacifiCorp to $1.5 billion of short-term debt. As of March 31, 2016, PacifiCorp had no short-term debt outstanding. As of December 31, 2015, PacifiCorp had $20 million of short-term debt outstanding at a weighted average interest rate of 0.65%.

Long-term Debt

PacifiCorp currently has regulatory authority from the OPUC and the IPUC to issue an additional $1.325 billion of long-term debt. PacifiCorp must make a notice filing with the WUTC prior to any future issuance.

Future Uses of Cash

PacifiCorp has available a variety of sources of liquidity and capital resources, both internal and external, including net cash flows from operating activities, public and private debt offerings, the issuance of commercial paper, the use of unsecured revolving credit facilities, capital contributions and other sources. These sources are expected to provide funds required for current operations, capital expenditures, debt retirements and other capital requirements. The availability and terms under which PacifiCorp has access to external financing depends on a variety of factors, including PacifiCorp's credit ratings, investors' judgment of risk and conditions in the overall capital markets, including the condition of the utility industry.

Capital Expenditures

PacifiCorp has significant future capital requirements. Capital expenditure needs are reviewed regularly by management and may change significantly as a result of these reviews, which may consider, among other factors, changes in environmental and other rules and regulations; impacts to customers' rates; outcomes of regulatory proceedings; changes in income tax laws; general business conditions; load projections; system reliability standards; the cost and efficiency of construction labor, equipment and materials; commodity prices; and the cost and availability of capital.

61

Historical and forecast capital expenditures, each of which exclude amounts for non-cash equity AFUDC and other non-cash items, are as follows (in millions):

	Three-Month Periods				Annual
	Ended March 31,				Forecast
	2015		2016		2016
Transmission system investment	$	38	$	32	$	97
Environmental	26		15		63
Operating and other	144		153		635
Total	$	208	$	200	$	795

PacifiCorp's historical and forecast capital expenditures include the following:

• 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.

• 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.

Integrated Resource Plan

In March 2015, PacifiCorp filed its 2015 Integrated Resource Plan ("IRP") with the state commissions. In 2015 the WPSC accepted the 2015 IRP into its files and the UPSC, IPUC and WUTC acknowledged the 2015 IRP. In February 2016, the OPUC acknowledged the 2015 IRP with one exception. In March 2016, PacifiCorp filed its update to the 2015 IRP with the state commissions.

Contractual Obligations

As of March 31, 2016, there have been no material changes outside the normal course of business in contractual obligations from the information provided in Item 7 of PacifiCorp's Annual Report on Form 10-K for the year ended December 31, 2015.

Regulatory Matters

PacifiCorp is subject to comprehensive regulation. Refer to "Regulatory Matters" in Berkshire Hathaway Energy's Part I, Item 2 of this Form 10-Q for discussion regarding PacifiCorp's current regulatory matters.

Environmental Laws and Regulations

PacifiCorp is subject to federal, state and local laws and regulations regarding air and water quality, renewable portfolio standards, emissions performance standards, climate change, coal combustion byproduct disposal, hazardous and solid waste disposal, protected species and other environmental matters that have the potential to impact PacifiCorp's current and future operations. In addition to imposing continuing compliance obligations and capital expenditure requirements, these laws and regulations provide regulators with the authority to levy substantial penalties for noncompliance including fines, injunctive relief and other sanctions. These laws and regulations are administered by the EPA and various state and local agencies. All such laws and regulations are subject to a range of interpretation, which may ultimately be resolved by the courts. Environmental laws and regulations continue to evolve, and PacifiCorp is unable to predict the impact of the changing laws and regulations on its operations and consolidated financial results. PacifiCorp believes it is in material compliance with all applicable laws and regulations. Refer to "Liquidity and Capital Resources" for discussion of PacifiCorp's forecast environmental-related capital expenditures.

Refer to "Environmental Laws and Regulations" in Berkshire Hathaway Energy's Part I, Item 2 of this Form 10-Q for additional information regarding environmental laws.

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New Accounting Pronouncements

For a discussion of new accounting pronouncements affecting PacifiCorp, refer to Note 2 of Notes to Consolidated Financial Statements in Part I, Item 1 of the Form 10-Q.

Critical Accounting Estimates

Certain accounting measurements require management to make estimates and judgments concerning transactions that will be settled several years in the future. Amounts recognized on the Consolidated Financial Statements based on such estimates involve numerous assumptions subject to varying and potentially significant degrees of judgment and uncertainty and will likely change in the future as additional information becomes available. Estimates are used for, but not limited to, the accounting for the effects of certain types of regulation, derivatives, pension and other postretirement benefits, income taxes and revenue recognition-unbilled revenue. For additional discussion of PacifiCorp's critical accounting estimates, see Item 7 of PacifiCorp's Annual Report on Form 10-K for the year ended December 31, 2015. There have been no significant changes in PacifiCorp's assumptions regarding critical accounting estimates since December 31, 2015.

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MidAmerican Funding, LLC and its subsidiaries and MidAmerican Energy Company

Consolidated Financial Section

64

PART I

Item 1. Financial Statements

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and Shareholder of

MidAmerican Energy Company

Des Moines, Iowa

We have reviewed the accompanying balance sheet of MidAmerican Energy Company ("MidAmerican Energy") as of March 31, 2016, and the related statements of operations, comprehensive income, changes in equity and cash flows for the three-month periods ended March 31, 2016 and 2015. These interim financial statements are the responsibility of MidAmerican Energy's management.

We conducted our reviews in accordance with the standards of the Public Company Accounting Oversight Board (United States). A review of interim financial information consists principally of applying analytical procedures and making inquiries of persons responsible for financial and accounting matters. It is substantially less in scope than an audit conducted in accordance with the standards of the Public Company Accounting Oversight Board (United States), the objective of which is the expression of an opinion regarding the financial statements taken as a whole. Accordingly, we do not express such an opinion.

Based on our reviews, we are not aware of any material modifications that should be made to such interim financial statements for them to be in conformity with accounting principles generally accepted in the United States of America.

We have previously audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the balance sheet of MidAmerican Energy Company as of December 31, 2015, and the related statements of operations, comprehensive income, changes in equity and cash flows for the year then ended (not presented herein) prior to reclassification for the discontinued operations described in Note 3 to the accompanying financial information; and in our report dated February 26, 2016, we expressed an unqualified opinion on those financial statements. We also audited the adjustments described in Note 3 to reclassify the December 31, 2015 balance sheet of MidAmerican Energy Company for discontinued operations. In our opinion, such adjustments are appropriate and have been properly applied to the previously issued financial statements in deriving the accompanying retrospectively adjusted financial information as of December 31, 2015.

/s/ Deloitte & Touche LLP

Des Moines, Iowa

May 6, 2016

65

MIDAMERICAN ENERGY COMPANY

BALANCE SHEETS

(Amounts in millions)

	As of
	March 31,		December 31,
	2016		2015
ASSETS
Current assets:
Cash and cash equivalents	$	1	$	103
Receivables, net	198		342
Income taxes receivable	126		104
Inventories	239		238
Other current assets	28		58
Total current assets	592		845
Property, plant and equipment, net	11,759		11,723
Regulatory assets	1,078		1,044
Investments and restricted cash and investments	647		634
Other assets	138		139
Total assets	$	14,214	$	14,385

The accompanying notes are an integral part of these financial statements.

66

MIDAMERICAN ENERGY COMPANY

BALANCE SHEETS (continued)

(Amounts in millions)

	As of
	March 31,			December 31,
	2016			2015
LIABILITIES AND SHAREHOLDER'S EQUITY
Current liabilities:
Accounts payable	$	197		$	426
Accrued interest	47			46
Accrued property, income and other taxes	100			125
Short-term debt	70			—
Current portion of long-term debt	34			34
Other current liabilities	127			166
Total current liabilities	575			797
Long-term debt	4,234			4,237
Deferred income taxes	3,133			3,061
Regulatory liabilities	848			831
Asset retirement obligations	484			488
Other long-term liabilities	248			266
Total liabilities	9,522			9,680
Commitments and contingencies (Note 9)
Shareholder's equity:
Common stock - 350 shares authorized, no par value, 71 shares issued and outstanding	—			—
Additional paid-in capital	561			561
Retained earnings	4,133			4,174
Accumulated other comprehensive loss, net	(2		)	(30		)
Total shareholder's equity	4,692			4,705
Total liabilities and shareholder's equity	$	14,214		$	14,385

The accompanying notes are an integral part of these financial statements.

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MIDAMERICAN ENERGY COMPANY

STATEMENTS OF OPERATIONS (Unaudited)

(Amounts in millions)

	Three-Month Periods
	Ended March 31,
	2016			2015
Operating revenue:
Regulated electric	$	399		$	426
Regulated gas and other	226			296
Total operating revenue	625			722
Operating costs and expenses:
Cost of fuel, energy and capacity	92			122
Cost of gas sold and other	135			201
Operations and maintenance	160			170
Depreciation and amortization	110			100
Property and other taxes	28			29
Total operating costs and expenses	525			622
Operating income	100			100
Other income and (expense):
Interest expense	(49		)	(44		)
Allowance for borrowed funds	1			2
Allowance for equity funds	4			5
Other, net	3			3
Total other income and (expense)	(41		)	(34		)
Income before income tax benefit	59			66
Income tax benefit	(17		)	(24		)
Income from continuing operations	76			90
Discontinued operations (Note 3):
Income from discontinued operations	—			7
Income tax expense	—			3
Income on discontinued operations	—			4
Net income	$	76		$	94

The accompanying notes are an integral part of these financial statements.

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MIDAMERICAN ENERGY COMPANY

STATEMENTS OF COMPREHENSIVE INCOME (Unaudited)

(Amounts in millions)

	Three-Month Periods
	Ended March 31,
	2016		2015
Net income	$	76	$	94
Other comprehensive income, net of tax:
Unrealized gains on available-for-sale securities, net of tax of $- and $-	1		—
Unrealized gains on cash flow hedges, net of tax of $- and $2	—		2
Total other comprehensive income, net of tax	1		2
Comprehensive income	$	77	$	96

The accompanying notes are an integral part of these financial statements.

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MIDAMERICAN ENERGY COMPANY

STATEMENTS OF CHANGES IN EQUITY (Unaudited)

(Amounts in millions)

	Common Stock		Retained Earnings			Accumulated Other Comprehensive Loss, Net			Total Equity
Balance, December 31, 2014	$	561	$	3,712		$	(23	)	$	4,250
Net income	—		94			—			94
Other comprehensive income	—		—			2			2
Balance, March 31, 2015	$	561	$	3,806		$	(21	)	$	4,346
Balance, December 31, 2015	$	561	$	4,174		$	(30	)	$	4,705
Net income	—		76			—			76
Other comprehensive income	—		—			1			1
Dividend (Note 3)	—		(117		)	27			(90		)
Balance, March 31, 2016	$	561	$	4,133		$	(2	)	$	4,692

The accompanying notes are an integral part of these financial statements.

70

MIDAMERICAN ENERGY COMPANY

STATEMENTS OF CASH FLOWS (Unaudited)

(Amounts in millions)

	Three-Month Periods
	Ended March 31,
	2016			2015
Cash flows from operating activities:
Net income	$	76		$	94
Adjustments to reconcile net income to net cash flows from operating activities:
Depreciation and amortization	110			100
Deferred income taxes and amortization of investment tax credits	11			—
Changes in other assets and liabilities	11			11
Other, net	(13		)	7
Changes in other operating assets and liabilities:
Receivables, net	28			43
Inventories	(1		)	34
Derivative collateral, net	2			15
Contributions to pension and other postretirement benefit plans, net	(2		)	(2		)
Accounts payable	4			(45		)
Accrued property, income and other taxes, net	(48		)	(40		)
Other current assets and liabilities	(6		)	(11		)
Net cash flows from operating activities	172			206
Cash flows from investing activities:
Utility construction expenditures	(332		)	(244		)
Purchases of available-for-sale securities	(34		)	(27		)
Proceeds from sales of available-for-sale securities	29			19
Other, net	(3		)	2
Net cash flows from investing activities	(340		)	(250		)
Cash flows from financing activities:
Repayments of long-term debt	(4		)	—
Net proceeds from short-term debt	70			15
Net cash flows from financing activities	66			15
Net change in cash and cash equivalents	(102		)	(29		)
Cash and cash equivalents at beginning of period	103			29
Cash and cash equivalents at end of period	$	1		$	—

The accompanying notes are an integral part of these financial statements.

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MIDAMERICAN ENERGY COMPANY

NOTES TO FINANCIAL STATEMENTS

(Unaudited)

(1) General

MidAmerican Energy Company ("MidAmerican Energy") is a public utility with electric and natural gas operations and is the principal subsidiary of MHC Inc. ("MHC"). MHC is a holding company that conducts no business other than the ownership of its subsidiaries and related corporate services. MHC's nonregulated subsidiaries include Midwest Capital Group, Inc. and MEC Construction Services Co. MHC is the direct, wholly owned subsidiary of MidAmerican Funding, LLC ("MidAmerican Funding"), which is an Iowa limited liability company with Berkshire Hathaway Energy Company ("BHE") as its sole member. BHE is a consolidated subsidiary of Berkshire Hathaway Inc. ("Berkshire Hathaway").

The unaudited Financial Statements have been prepared in accordance with accounting principles generally accepted in the United States of America ("GAAP") for interim financial information and the United States Securities and Exchange Commission's rules and regulations for Form 10-Q and Article 10 of Regulation S-X. Accordingly, they do not include all of the disclosures required by GAAP for annual financial statements. Management believes the unaudited Financial Statements contain all adjustments (consisting only of normal recurring adjustments) considered necessary for the fair presentation of the unaudited Financial Statements as of March 31, 2016, and for the three-month periods ended March 31, 2016 and 2015. Certain amounts in the prior period Financial Statements have been reclassified to conform to the current period presentation. Such reclassifications did not impact previously reported operating income, net income or retained earnings. The results of operations for the three-month periods ended March 31, 2016, are not necessarily indicative of the results to be expected for the full year.

The preparation of the unaudited Financial Statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities at the date of the unaudited Financial Statements and the reported amounts of revenue and expenses during the period. Actual results may differ from the estimates used in preparing the unaudited Financial Statements. Note 2 of Notes to Financial Statements included in MidAmerican Energy's Annual Report on Form 10-K for the year ended December 31, 2015, describes the most significant accounting policies used in the preparation of the unaudited Financial Statements. There have been no significant changes in MidAmerican Energy's assumptions regarding significant accounting estimates and policies during the three-month period ended March 31, 2016.

(2) New Accounting Pronouncements

In February 2016, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") No. 2016-02, which creates FASB Accounting Standards Codification ("ASC") Topic 842, "Leases" and supersedes Topic 840 "Leases." This guidance increases transparency and comparability among entities by recording lease assets and lease liabilities on the balance sheet and disclosing key information about leasing arrangements. A lessee should recognize in the balance sheet a liability to make lease payments (the lease liability) and a right-of-use asset representing its right to use the underlying asset for the lease term. The recognition, measurement, and presentation of expenses and cash flows arising from a lease by a lessee have not significantly changed from previous guidance. This guidance is effective for interim and annual reporting periods beginning after December 15, 2018, with early adoption permitted, and is required to be adopted using a modified retrospective approach. MidAmerican Energy is currently evaluating the impact of adopting this guidance on its Financial Statements and disclosures included within Notes to Financial Statements.

In January 2016, the FASB issued ASU No. 2016-01, which amends FASB ASC Subtopic 825-10, "Financial Instruments - Overall." The amendments in this guidance address certain aspects of recognition, measurement, presentation and disclosure of financial instruments including a requirement that all investments in equity securities that do not qualify for equity method accounting or result in consolidation of the investee be measured at fair value with changes in fair value recognized in net income. This guidance is effective for interim and annual reporting periods beginning after December 15, 2017, with early adoption not permitted, and is required to be adopted prospectively by means of a cumulative-effect adjustment to the balance sheet as of the beginning of the fiscal year of adoption. MidAmerican Energy is currently evaluating the impact of adopting this guidance on its Financial Statements and disclosures included within Notes to Financial Statements.

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In May 2014, the FASB issued ASU No. 2014-09, which creates FASB ASC Topic 606, "Revenue from Contracts with Customers" and supersedes ASC Topic 605, "Revenue Recognition." The guidance replaces industry-specific guidance and establishes a single five-step model to identify and recognize revenue. The core principle of the guidance is that an entity should recognize revenue upon transfer of control of promised goods or services to customers in an amount that reflects the consideration to which an entity expects to be entitled in exchange for those goods or services. Additionally, the guidance requires the entity to disclose further quantitative and qualitative information regarding the nature and amount of revenues arising from contracts with customers, as well as other information about the significant judgments and estimates used in recognizing revenues from contracts with customers. In August 2015, the FASB issued ASU No.2015-14, which defers the effective date of ASU No. 2014-09 one year to interim and annual reporting periods beginning after December 15, 2017. This guidance may be adopted retrospectively or under a modified retrospective method where the cumulative effect is recognized at the date of initial application. MidAmerican Energy is currently evaluating the impact of adopting this guidance on its Financial Statements and disclosures included within Notes to Financial Statements.

(3) Discontinued Operations

On January 1, 2016, MidAmerican Energy transferred the assets and liabilities of its unregulated retail services business to a subsidiary of BHE. The transfer was made at MidAmerican Energy’s carrying value of the assets and liabilities as of December 31, 2015, and was recorded by MidAmerican Energy as a noncash dividend as summarized in the table below. Financial results of the unregulated retail services business for the three-month period ended March 31, 2015, have been reclassified to discontinued operations in the Statement of Operations. Operating revenue and cost of sales of the unregulated retail services business for the three-month period ended March 31, 2015, totaled $224 million and $212 million, respectively. Cash flows from operating activities of the unregulated retail services business totaled $17 million for the three-month period ended March 31, 2015, and are reflected in the Statement of Cash Flows. Assets, liabilities and equity of the unregulated retail services business reflected in the Balance Sheet as of December 31, 2015, are as follows (in millions):

Receivables	$	115
Derivative assets	41
Deferred income taxes	21
Accounts payable	(49		)
Derivative liabilities	(42		)
Other assets and liabilities, net	4
Dividend, excluding accumulated other comprehensive loss, net	90
Accumulated other comprehensive loss, net	27
Dividend, including accumulated other comprehensive loss, net	$	117

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(4) Property, Plant and Equipment, Net

Property, plant and equipment, net consists of the following (in millions):

		As of
		March 31,			December 31,
	Depreciable Life	2016			2015
Utility plant in service, net:
Generation	20-70 years	$	10,499		$	10,404
Transmission	52-70 years	1,304			1,305
Electric distribution	20-70 years	3,086			3,059
Gas distribution	28-70 years	1,519			1,507
Utility plant in service		16,408			16,275
Accumulated depreciation and amortization		(5,312		)	(5,229		)
Utility plant in service, net		11,096			11,046
Nonregulated property, net:
Nonregulated property gross	5-45 years	7			15
Accumulated depreciation and amortization		(1		)	(5		)
Nonregulated property, net		6			10
		11,102			11,056
Construction work in progress		657			667
Property, plant and equipment, net		$	11,759		$	11,723

(5) Income Taxes

A reconciliation of the federal statutory income tax rate to MidAmerican Energy's effective income tax rate applicable to income before income tax benefit from continuing operations is as follows:

	Three-Month Periods
	Ended March 31,
	2016		2015
Federal statutory income tax rate	35	%	35	%
Income tax credits	(57	)	(63	)
State income tax, net of federal income tax benefit	5		4
Effects of ratemaking	(12	)	(11	)
Other, net	—		(1	)
Effective income tax rate	(29	)%	(36	)%

Income tax credits relate primarily to production tax credits from MidAmerican Energy's wind-powered generating facilities. Federal renewable electricity production tax credits are earned as energy from qualifying wind-powered generating facilities is produced and sold and are based on a per-kilowatt hour rate pursuant to the applicable federal income tax law. Wind-powered generating facilities are eligible for the credits for 10 years from the date the qualifying generating facilities are placed in service.

Berkshire Hathaway includes BHE and subsidiaries in its United States federal income tax return. Consistent with established regulatory practice, MidAmerican Energy's provision for income taxes has been computed on a stand-alone basis, and substantially all of its currently payable or receivable income taxes are remitted to or received from BHE. MidAmerican Energy received net cash payments for income taxes from BHE totaling $4 million and $- million for the three-month periods ended March 31, 2016 and 2015, respectively.

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(6) Employee Benefit Plans

MidAmerican Energy sponsors a noncontributory defined benefit pension plan covering a majority of all employees of BHE and its domestic energy subsidiaries other than PacifiCorp and NV Energy, Inc. MidAmerican Energy also sponsors certain postretirement healthcare and life insurance benefits covering substantially all retired employees of BHE and its domestic energy subsidiaries other than PacifiCorp and NV Energy, Inc.

Net periodic benefit cost (credit) for the plans of MidAmerican Energy and the aforementioned affiliates included the following components (in millions):

	Three-Month Periods
	Ended March 31,
	2016			2015
Pension:
Service cost	$	3		$	3
Interest cost	8			8
Expected return on plan assets	(11		)	(11		)
Net periodic benefit cost	$	—		$	—
Other postretirement:
Service cost	$	1		$	2
Interest cost	2			2
Expected return on plan assets	(3		)	(4		)
Net amortization	(1		)	(1		)
Net periodic benefit credit	$	(1	)	$	(1	)

Employer contributions to the pension and other postretirement benefit plans are expected to be $8 million and $1 million, respectively, during 2016. As of March 31, 2016, $2 million and $- million of contributions had been made to the pension and other postretirement benefit plans, respectively.

(7) Risk Management and Hedging Activities

MidAmerican Energy is exposed to the impact of market fluctuations in commodity prices and interest rates. MidAmerican Energy is principally exposed to electricity, natural gas, coal and fuel oil commodity price risk as it has an obligation to serve retail customer load in its regulated service territory. Prior to January 1, 2016, MidAmerican Energy also provided nonregulated retail electricity and natural gas services in competitive markets, which created contractual obligations to provide electric and natural gas services. MidAmerican Energy's load and generating facilities represent substantial underlying commodity positions. Exposures to commodity prices consist mainly of variations in the price of fuel required to generate electricity, wholesale electricity that is purchased and sold, and natural gas supply for retail customers. Commodity prices are subject to wide price swings as supply and demand are impacted by, among many other unpredictable items, weather; market liquidity; generating facility availability; customer usage; storage; and transmission and transportation constraints. Interest rate risk exists on variable-rate debt and future debt issuances. MidAmerican Energy does not engage in a material amount of proprietary trading activities.

MidAmerican Energy has established a risk management process that is designed to identify, assess, manage, mitigate, monitor and report each of the various types of risk involved in its business. To mitigate a portion of its commodity price risk, MidAmerican Energy uses commodity derivative contracts, which may include forwards, futures, options, swaps and other agreements, to effectively secure future supply or sell future production generally at fixed prices. MidAmerican Energy manages its interest rate risk by limiting its exposure to variable interest rates primarily through the issuance of fixed-rate long-term debt and by monitoring market changes in interest rates. Additionally, MidAmerican Energy may from time to time enter into interest rate derivative contracts, such as interest rate swaps or locks, to mitigate its exposure to interest rate risk. MidAmerican Energy does not hedge all of its commodity price and interest rate risks, thereby exposing the unhedged portion to changes in market prices.

There have been no significant changes in MidAmerican Energy's accounting policies related to derivatives. Refer to Note 8 for additional information on derivative contracts and to Note 3 for a discussion of discontinued operations.

75

The following table, which reflects master netting arrangements and excludes contracts that have been designated as normal under the normal purchases or normal sales exception afforded by GAAP, summarizes the fair value of MidAmerican Energy's derivative contracts, on a gross basis, and reconciles those amounts to the amounts presented on a net basis on the Balance Sheets (in millions):

	Other Current Assets		Other Assets		Other Current Liabilities			Other Long-term Liabilities			Total
As of March 31, 2016:
Not designated as hedging contracts(1)(2):
Commodity assets	$	3	$	—	$	1		$	—		$	4
Commodity liabilities	—		—		(11		)	(1		)	(12		)
Total	3		—		(10		)	(1		)	(8		)
Designated as hedging contracts(2):
Commodity assets	—		—		—			—			—
Commodity liabilities	—		—		—			—			—
Total	—		—		—			—			—
Total derivatives	3		—		(10		)	(1		)	(8		)
Cash collateral receivable	—		—		6			—			6
Total derivatives - net basis	$	3	$	—	$	(4	)	$	(1	)	$	(2	)

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, and as of March 31, 2016 and December 31, 2015, a net regulatory asset of $11 million and $20 million, respectively, was recorded related to the net derivative liability of $8 million and $26 million, respectively.

(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.

76

Not Designated as Hedging Contracts

The following table reconciles the beginning and ending balances of MidAmerican Energy's net regulatory assets and summarizes the pre-tax gains and losses on commodity derivative contracts recognized in net regulatory assets, as well as amounts reclassified to earnings (in millions):

	Three-Month Periods
	Ended March 31,
	2016			2015
Beginning balance	$	20		$	38
Changes in fair value recognized in net regulatory assets	6			2
Net losses reclassified to operating revenue	(8		)	(16		)
Net losses reclassified to cost of gas sold	(7		)	(6		)
Ending balance	$	11		$	18

Designated as Hedging Contracts

MidAmerican Energy used commodity derivative contracts accounted for as cash flow hedges to hedge electricity and natural gas commodity prices related to its unregulated retail services business, which was transferred to a subsidiary of BHE. The following table reconciles the beginning and ending balances of MidAmerican Energy's accumulated other comprehensive loss (pre-tax) and summarizes pre-tax gains and losses on commodity derivative contracts designated and qualifying as cash flow hedges recognized in other comprehensive income ("OCI"), as well as amounts reclassified to earnings (in millions):

	Three-Month Periods
	Ended March 31,
	2016			2015
Beginning balance	$	45		$	34
Transfer to affiliate	(45		)	—
Changes in fair value recognized in OCI	—			(6		)
Net gains reclassified to nonregulated cost of sales	—			2
Ending balance	$	—		$	30

Derivative Contract Volumes

The following table summarizes the net notional amounts of outstanding commodity derivative contracts with fixed price terms that comprise the mark-to-market values as of (in millions):

	Unit of	March 31,	December 31,
	Measure	2016	2015
Electricity purchases	Megawatt hours	—	15
Natural gas purchases	Decatherms	12	17

77

Credit Risk

MidAmerican Energy is exposed to counterparty credit risk associated with wholesale energy supply and marketing activities with other utilities, energy marketing companies, financial institutions and other market participants. Credit risk may be concentrated to the extent MidAmerican Energy's counterparties have similar economic, industry or other characteristics and due to direct or indirect relationships among the counterparties. Before entering into a transaction, MidAmerican Energy analyzes the financial condition of each significant wholesale counterparty, establishes limits on the amount of unsecured credit to be extended to each counterparty, and evaluates the appropriateness of unsecured credit limits on an ongoing basis. To further mitigate wholesale counterparty credit risk, MidAmerican Energy enters into netting and collateral arrangements that may include margining and cross-product netting agreements and obtains third-party guarantees, letters of credit and cash deposits. If required, MidAmerican Energy exercises rights under these arrangements, including calling on the counterparty's credit support arrangement.

Collateral and Contingent Features

In accordance with industry practice, certain wholesale derivative contracts contain credit support provisions that in part base MidAmerican Energy's collateral requirements on its credit ratings for senior unsecured debt as reported by one or more of the three recognized credit rating agencies. These derivative contracts may either specifically provide bilateral rights to demand cash or other security if credit exposures on a net basis exceed specified rating-dependent threshold levels ("credit-risk-related contingent features") or provide the right for counterparties to demand "adequate assurance," or in some cases terminate the contract, in the event of a material adverse change in MidAmerican Energy's creditworthiness. These rights can vary by contract and by counterparty. As of March 31, 2016, MidAmerican Energy's credit ratings from the three recognized credit rating agencies were investment grade.

The aggregate fair value of MidAmerican Energy's derivative contracts in liability positions with specific credit-risk-related contingent features totaled $7 million and $66 million as of March 31, 2016 and December 31, 2015, respectively, for which MidAmerican Energy had posted collateral of $- million at each date. If all credit-risk-related contingent features for derivative contracts in liability positions had been triggered as of March 31, 2016 and December 31, 2015, MidAmerican Energy would have been required to post $4 million and $55 million, respectively, of additional collateral. MidAmerican Energy's collateral requirements could fluctuate considerably due to market price volatility, changes in credit ratings, changes in legislation or regulation, or other factors. MidAmerican Energy's exposure to contingent features declined significantly as a result of the transfer of its unregulated retail services business to a subsidiary of BHE.

(8) Fair Value Measurements

The carrying value of MidAmerican Energy's cash, certain cash equivalents, receivables, payables, accrued liabilities and short-term borrowings approximates fair value because of the short-term maturity of these instruments. MidAmerican Energy has various financial assets and liabilities that are measured at fair value on the Financial Statements using inputs from the three levels of the fair value hierarchy. A financial asset or liability classification within the hierarchy is determined based on the lowest level input that is significant to the fair value measurement. The three levels are as follows:

• 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.

78

The following table presents MidAmerican Energy's assets and liabilities recognized on the Balance Sheets and measured at fair value on a recurring basis (in millions):

	Input Levels for Fair Value Measurements
	Level 1			Level 2			Level 3			Other(1)			Total
As of March 31, 2016:
Assets:
Commodity derivatives	$	—		$	3		$	1		$	(1	)	$	3
Money market mutual funds(2)	4			—			—			—			4
Debt securities:
United States government obligations	142			—			—			—			142
International government obligations	—			2			—			—			2
Corporate obligations	—			34			—			—			34
Municipal obligations	—			2			—			—			2
Agency, asset and mortgage-backed obligations	—			4			—			—			4
Auction rate securities	—			—			26			—			26
Equity securities:
United States companies	242			—			—			—			242
International companies	7			—			—			—			7
Investment funds	9			—			—			—			9
	$	404		$	45		$	27		$	(1	)	$	475
Liabilities - commodity derivatives	$	(3	)	$	(4	)	$	(5	)	$	7		$	(5	)

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 $6 million and $28 million as of March 31, 2016 and December 31, 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.

79

Derivative contracts are recorded on the Balance Sheets as either assets or liabilities and are stated at estimated fair value unless they are designated as normal purchases or normal sales and qualify for the exception afforded by GAAP. When available, the fair value of derivative contracts is estimated using unadjusted quoted prices for identical contracts in the market in which MidAmerican Energy transacts. When quoted prices for identical contracts are not available, MidAmerican Energy uses forward price curves. Forward price curves represent MidAmerican Energy's estimates of the prices at which a buyer or seller could contract today for delivery or settlement at future dates. MidAmerican Energy bases its forward price curves upon market price quotations, when available, or internally developed and commercial models, with internal and external fundamental data inputs. Market price quotations are obtained from independent brokers, exchanges, direct communication with market participants and actual transactions executed by MidAmerican Energy. Market price quotations are generally readily obtainable for the applicable term of MidAmerican Energy's outstanding derivative contracts; therefore, MidAmerican Energy's forward price curves reflect observable market quotes. Market price quotations for certain electricity and natural gas trading hubs are not as readily obtainable due to the length of the contract. Given that limited market data exists for these contracts, as well as for those contracts that are not actively traded, MidAmerican Energy uses forward price curves derived from internal models based on perceived pricing relationships to major trading hubs that are based on unobservable inputs. The estimated fair value of these derivative contracts is a function of underlying forward commodity prices, interest rates, related volatility, counterparty creditworthiness and duration of contracts. Refer to Note 7 for further discussion regarding MidAmerican Energy's risk management and hedging activities.

MidAmerican Energy's investments in money market mutual funds and debt and equity securities are stated at fair value and are primarily accounted for as available-for-sale securities. When available, a readily observable quoted market price or net asset value of an identical security in an active market is used to record the fair value. In the absence of a quoted market price or net asset value of an identical security, the fair value is determined using pricing models or net asset values based on observable market inputs and quoted market prices of securities with similar characteristics. The fair value of MidAmerican Energy's investments in auction rate securities, where there is no current liquid market, is determined using pricing models based on available observable market data and MidAmerican Energy's judgment about the assumptions, including liquidity and nonperformance risks, which market participants would use when pricing the asset.

The following table reconciles the beginning and ending balances of MidAmerican Energy's assets and liabilities measured at fair value on a recurring basis using significant Level 3 inputs (in millions):

	Three-Month Periods
	Ended March 31,
	Commodity Derivatives			Auction Rate Securities
2016:
Beginning balance	$	(6	)	$	26
Transfer to affiliate	(4		)	—
Changes in fair value recognized in OCI	—			1
Changes in fair value recognized in net regulatory assets	(1		)	—
Sales	—			(1		)
Settlements	7			—
Ending balance	$	(4	)	$	26
2015:
Beginning balance	$	12		$	26
Changes included in earnings	2			—
Changes in fair value recognized in OCI	1			—
Settlements	(6		)	—
Ending balance	$	9		$	26

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MidAmerican Energy's long-term debt is carried at cost on the Balance Sheets. The fair value of MidAmerican Energy's long-term debt is a Level 2 fair value measurement and has been estimated based upon quoted market prices, where available, or at the present value of future cash flows discounted at rates consistent with comparable maturities with similar credit risks. The carrying value of MidAmerican Energy's variable-rate long-term debt approximates fair value because of the frequent repricing of these instruments at market rates. The following table presents the carrying value and estimated fair value of MidAmerican Energy's long-term debt (in millions):

	As of March 31, 2016				As of December 31, 2015
	Carrying Value		Fair Value		Carrying Value		Fair Value
Long-term debt	$	4,268	$	4,847	$	4,271	$	4,636

(9) Commitments and Contingencies

Legal Matters

MidAmerican Energy is party to a variety of legal actions arising out of the normal course of business. Plaintiffs occasionally seek punitive or exemplary damages. MidAmerican Energy does not believe that such normal and routine litigation will have a material impact on its financial results.

Environmental Laws and Regulations

MidAmerican Energy is subject to federal, state and local laws and regulations regarding air and water quality, emissions performance standards, climate change, coal combustion byproduct disposal, hazardous and solid waste disposal, protected species and other environmental matters that have the potential to impact its current and future operations. MidAmerican Energy believes it is in material compliance with all applicable laws and regulations.

(10) Components of Accumulated Other Comprehensive Income (Loss), Net

The following table shows the change in accumulated other comprehensive income (loss), net ("AOCI") by each component of other comprehensive income, net of applicable income taxes (in millions):

	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 income	—			2			2
Balance at March 31, 2015	$	(3	)	$	(18	)	$	(21	)
Balance, December 31, 2015	$	(3	)	$	(27	)	$	(30	)
Other comprehensive income	1			—			1
Dividend (Note 3)	—			27			27
Balance, March 31, 2016	$	(2	)	$	—		$	(2	)

For information regarding cash flow hedge reclassifications from AOCI to net income in their entirety, refer to Note 7.

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(11) Segment Information

MidAmerican Energy has identified two reportable segments: regulated electric and regulated gas. The previously reported nonregulated energy segment consisted substantially of MidAmerican Energy's unregulated retail services business, which was transferred to a subsidiary of BHE and is excluded from the information presented below. Refer to Note 3 for further discussion. The regulated electric segment derives most of its revenue from regulated retail sales of electricity to residential, commercial, and industrial customers and from wholesale sales. The regulated gas segment derives most of its revenue from regulated retail sales of natural gas to residential, commercial, and industrial customers and also obtains revenue by transporting gas owned by others through its distribution system. Pricing for regulated electric and regulated gas sales are established separately by regulatory agencies; therefore, management also reviews each segment separately to make decisions regarding allocation of resources and in evaluating performance. Common operating costs, interest income, interest expense and income tax expense are allocated to each segment based on certain factors, which primarily relate to the nature of the cost. "Other" in the tables below consists of the financial results and assets of remaining nonregulated operations.

The following tables provide information on a reportable segment basis (in millions):

	Three-Month Periods
	Ended March 31,
	2016		2015
Operating revenue:
Regulated electric	$	399	$	426
Regulated gas	226		295
Other	—		1
Total operating revenue	$	625	$	722
Depreciation and amortization:
Regulated electric	$	99	$	90
Regulated gas	11		10
Total depreciation and amortization	$	110	$	100
Operating income:
Regulated electric	$	57	$	53
Regulated gas	43		47
Total operating income	$	100	$	100

	As of
	March 31, 2016		December 31, 2015
Total assets:
Regulated electric	$	13,015	$	12,970
Regulated gas	1,199		1,251
Other(1)	—		164
Total assets	$	14,214	$	14,385

(1) Other total assets for December 31, 2015, includes amounts for MidAmerican Energy's unregulated retail services business transferred to a subsidiary of BHE.

82

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Managers and Member of

MidAmerican Funding, LLC

Des Moines, Iowa

We have reviewed the accompanying consolidated balance sheet of MidAmerican Funding, LLC and subsidiaries ("MidAmerican Funding") as of March 31, 2016, and the related consolidated statements of operations, comprehensive income, changes in equity and cash flows for the three-month periods ended March 31, 2016 and 2015. These interim financial statements are the responsibility of MidAmerican Funding's management.

We conducted our reviews in accordance with the standards of the Public Company Accounting Oversight Board (United States). A review of interim financial information consists principally of applying analytical procedures and making inquiries of persons responsible for financial and accounting matters. It is substantially less in scope than an audit conducted in accordance with the standards of the Public Company Accounting Oversight Board (United States), the objective of which is the expression of an opinion regarding the financial statements taken as a whole. Accordingly, we do not express such an opinion.

Based on our reviews, we are not aware of any material modifications that should be made to such consolidated interim financial statements for them to be in conformity with accounting principles generally accepted in the United States of America.

We have previously audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the consolidated balance sheet of MidAmerican Funding, LLC and subsidiaries as of December 31, 2015, and the related consolidated statements of operations, comprehensive income, changes in equity and cash flows for the year then ended (not presented herein) prior to reclassification for the discontinued operations described in Note 3 to the accompanying financial information; and in our report dated February 26, 2016, we expressed an unqualified opinion on those consolidated financial statements. We also audited the adjustments described in Note 3 to reclassify the December 31, 2015 balance sheet of MidAmerican Funding, LLC and subsidiaries for discontinued operations. In our opinion, such adjustments are appropriate and have been properly applied to the previously issued financial statements in deriving the accompanying retrospectively adjusted financial information as of December 31, 2015.

/s/ Deloitte & Touche LLP

Des Moines, Iowa

May 6, 2016

83

MIDAMERICAN FUNDING, LLC AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS

(Amounts in millions)

	As of
	March 31,		December 31,
	2016		2015
ASSETS
Current assets:
Cash and cash equivalents	$	2	$	103
Receivables, net	198		346
Income taxes receivable	127		104
Inventories	239		238
Other current assets	27		58
Total current assets	593		849
Property, plant and equipment, net	11,773		11,737
Goodwill	1,270		1,270
Regulatory assets	1,078		1,044
Investments and restricted cash and investments	649		636
Other assets	138		138
Total assets	$	15,501	$	15,674

The accompanying notes are an integral part of these consolidated financial statements.

84

MIDAMERICAN FUNDING, LLC AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS (continued)

(Amounts in millions)

	As of
	March 31,			December 31,
	2016			2015
LIABILITIES AND MEMBER'S EQUITY
Current liabilities:
Accounts payable	$	197		$	427
Accrued interest	49			53
Accrued property, income and other taxes	99			125
Note payable to affiliate	31			139
Short-term debt	70			—
Current portion of long-term debt	34			34
Other current liabilities	127			166
Total current liabilities	607			944
Long-term debt	4,560			4,563
Deferred income taxes	3,129			3,056
Regulatory liabilities	848			831
Asset retirement obligations	484			488
Other long-term liabilities	248			267
Total liabilities	9,876			10,149
Commitments and contingencies (Note 9)
Member's equity:
Paid-in capital	1,679			1,679
Retained earnings	3,948			3,876
Accumulated other comprehensive loss, net	(2		)	(30		)
Total member's equity	5,625			5,525
Total liabilities and member's equity	$	15,501		$	15,674

The accompanying notes are an integral part of these consolidated financial statements.

85

MIDAMERICAN FUNDING, LLC AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF OPERATIONS (Unaudited)

(Amounts in millions)

	Three-Month Periods
	Ended March 31,
	2016			2015
Operating revenue:
Regulated electric	$	399		$	426
Regulated gas and other	227			301
Total operating revenue	626			727
Operating costs and expenses:
Cost of fuel, energy and capacity	92			122
Cost of gas sold and other	135			205
Operations and maintenance	161			170
Depreciation and amortization	110			100
Property and other taxes	28			29
Total operating costs and expenses	526			626
Operating income	100			101
Other income and (expense):
Interest expense	(54		)	(50		)
Allowance for borrowed funds	1			2
Allowance for equity funds	4			5
Other, net	3			16
Total other income and (expense)	(46		)	(27		)
Income before income tax benefit	54			74
Income tax benefit	(19		)	(21		)
Income from continuing operations	73			95
Discontinued operations (Note 3):
Income from discontinued operations	—			7
Income tax expense	—			3
Income on discontinued operations	—			4
Net income	$	73		$	99

The accompanying notes are an integral part of these consolidated financial statements.

86

MIDAMERICAN FUNDING, LLC AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Unaudited)

(Amounts in millions)

	Three-Month Periods
	Ended March 31,
	2016		2015
Net income	$	73	$	99
Other comprehensive income, net of tax:
Unrealized gains on available-for-sale securities, net of tax of $- and $-	1		—
Unrealized gains on cash flow hedges, net of tax of $- and $2	—		2
Total other comprehensive income, net of tax	1		2
Comprehensive income	$	74	$	101

The accompanying notes are an integral part of these consolidated financial statements.

87

MIDAMERICAN FUNDING, LLC AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY (Unaudited)

(Amounts in millions)

	Paid-in Capital		Retained Earnings			Accumulated Other Comprehensive Loss, Net			Total Equity
Balance, December 31, 2014	$	1,679	$	3,417		$	(23	)	$	5,073
Net income	—		99			—			99
Other comprehensive income	—		—			2			2
Other equity transactions	—		1			—			1
Balance, March 31, 2015	$	1,679	$	3,517		$	(21	)	$	5,175
Balance, December 31, 2015	$	1,679	$	3,876		$	(30	)	$	5,525
Net income	—		73			—			73
Other comprehensive income	—		—			1			1
Transfer to affiliate	—		—			27			27
Other equity transactions	—		(1		)	—			(1		)
Balance, March 31, 2016	$	1,679	$	3,948		$	(2	)	$	5,625

The accompanying notes are an integral part of these consolidated financial statements.

88

MIDAMERICAN FUNDING, LLC AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited)

(Amounts in millions)

	Three-Month Periods
	Ended March 31,
	2016			2015
Cash flows from operating activities:
Net income	$	73		$	99
Adjustments to reconcile net income to net cash flows from operating activities:
Depreciation and amortization	110			100
Deferred income taxes and amortization of investment tax credits	11			—
Changes in other assets and liabilities	11			11
Other, net	(13		)	(6		)
Changes in other operating assets and liabilities:
Receivables, net	31			44
Inventories	(1		)	34
Derivative collateral, net	2			15
Contributions to pension and other postretirement benefit plans, net	(2		)	(2		)
Accounts payable	4			(45		)
Accrued property, income and other taxes, net	(51		)	(37		)
Other current assets and liabilities	(12		)	(16		)
Net cash flows from operating activities	163			197
Cash flows from investing activities:
Utility construction expenditures	(332		)	(244		)
Purchases of available-for-sale securities	(34		)	(27		)
Proceeds from sales of available-for-sale securities	29			19
Proceeds from sale of investment	—			13
Other, net	(2		)	2
Net cash flows from investing activities	(339		)	(237		)
Cash flows from financing activities:
Repayments of long-term debt	(4		)	—
Net change in note payable to affiliate	9			(4		)
Net proceeds from short-term debt	70			15
Net cash flows from financing activities	75			11
Net change in cash and cash equivalents	(101		)	(29		)
Cash and cash equivalents at beginning of period	103			30
Cash and cash equivalents at end of period	$	2		$	1

The accompanying notes are an integral part of these consolidated financial statements.

89

MIDAMERICAN FUNDING, LLC AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

(1) General

MidAmerican Funding, LLC ("MidAmerican Funding") is an Iowa limited liability company with Berkshire Hathaway Energy Company ("BHE") as its sole member. BHE is a consolidated subsidiary of Berkshire Hathaway Inc. ("Berkshire Hathaway"). MidAmerican Funding's direct, wholly owned subsidiary is MHC Inc. ("MHC"), which constitutes substantially all of MidAmerican Funding's assets, liabilities and business activities except those related to MidAmerican Funding's long-term debt securities. MHC conducts no business other than the ownership of its subsidiaries and related corporate services. MHC's principal subsidiary is MidAmerican Energy Company ("MidAmerican Energy"), a public utility with electric and natural gas operations. Direct, wholly owned nonregulated subsidiaries of MHC are Midwest Capital Group, Inc. and MEC Construction Services Co.

The unaudited Consolidated Financial Statements have been prepared in accordance with accounting principles generally accepted in the United States of America ("GAAP") for interim financial information and the United States Securities and Exchange Commission's rules and regulations for Form 10-Q and Article 10 of Regulation S-X. Accordingly, they do not include all of the disclosures required by GAAP for annual financial statements. Management believes the unaudited Consolidated Financial Statements contain all adjustments (consisting only of normal recurring adjustments) considered necessary for the fair presentation of the unaudited Consolidated Financial Statements as of March 31, 2016, and for the three-month periods ended March 31, 2016 and 2015. Certain amounts in the prior period Consolidated Financial Statements have been reclassified to conform to the current period presentation. Such reclassifications did not impact previously reported operating income, net income or retained earnings. The results of operations for the three-month periods ended March 31, 2016, are not necessarily indicative of the results to be expected for the full year.

The preparation of the unaudited Consolidated Financial Statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities at the date of the unaudited Consolidated Financial Statements and the reported amounts of revenue and expenses during the period. Actual results may differ from the estimates used in preparing the unaudited Consolidated Financial Statements. Note 2 of Notes to Consolidated Financial Statements included in MidAmerican Funding's Annual Report on Form 10-K for the year ended December 31, 2015, describes the most significant accounting policies used in the preparation of the unaudited Consolidated Financial Statements. There have been no significant changes in MidAmerican Funding's assumptions regarding significant accounting estimates and policies during the three-month period ended March 31, 2016.

(2) New Accounting Pronouncements

Refer to Note 2 of MidAmerican Energy's Notes to Financial Statements.

(3) Discontinued Operations

Refer to Note 3 of MidAmerican Energy's Notes to Financial Statements. The transfer of MidAmerican Energy's unregulated retail services business to a subsidiary of BHE repaid a portion of MHC's note payable to BHE.

(4) Property, Plant and Equipment, Net

Refer to Note 4 of MidAmerican Energy's Notes to Financial Statements. In addition to MidAmerican Energy's property, plant and equipment, net, MidAmerican Funding had nonregulated property gross of $22 million as of March 31, 2016 and December 31, 2015, and related accumulated depreciation and amortization of $8 million as of March 31, 2016 and December 31, 2015, which consisted primarily of a corporate aircraft owned by MHC.

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(5) Income Taxes

A reconciliation of the federal statutory income tax rate to MidAmerican Funding's effective income tax rate applicable to income before income tax benefit from continuing operations is as follows:

	Three-Month Periods
	Ended March 31,
	2016		2015
Federal statutory income tax rate	35	%	35	%
Income tax credits	(62	)	(55	)
State income tax, net of federal income tax benefit	5		3
Effects of ratemaking	(14	)	(10	)
Other, net	1		(1	)
Effective income tax rate	(35	)%	(28	)%

Income tax credits relate primarily to production tax credits from MidAmerican Energy's wind-powered generating facilities. Federal renewable electricity production tax credits are earned as energy from qualifying wind-powered generating facilities is produced and sold and are based on a per-kilowatt hour rate pursuant to the applicable federal income tax law. Wind-powered generating facilities are eligible for the credits for 10 years from the date the qualifying generating facilities are placed in service.

Berkshire Hathaway includes BHE and subsidiaries in its United States federal income tax return. Consistent with established regulatory practice, MidAmerican Funding's and MidAmerican Energy's provisions for income taxes have been computed on a stand-alone basis, and substantially all of their currently payable or receivable income taxes are remitted to or received from BHE. MidAmerican Funding received net cash payments for income taxes from BHE totaling $4 million and $- million for the three-month periods ended March 31, 2016 and 2015, respectively.

(6) Employee Benefit Plans

Refer to Note 6 of MidAmerican Energy's Notes to Financial Statements.

(7) Risk Management and Hedging Activities

Refer to Note 7 of MidAmerican Energy's Notes to Financial Statements.

(8) Fair Value Measurements

Refer to Note 8 of MidAmerican Energy's Notes to Financial Statements.

MidAmerican Funding's long-term debt is carried at cost on the Consolidated Financial Statements. The fair value of MidAmerican Funding's long-term debt is a Level 2 fair value measurement and has been estimated based upon quoted market prices, where available, or at the present value of future cash flows discounted at rates consistent with comparable maturities with similar credit risks. The carrying value of MidAmerican Funding's variable-rate long-term debt approximates fair value because of the frequent repricing of these instruments at market rates. The following table presents the carrying value and estimated fair value of MidAmerican Funding's long-term debt (in millions):

	As of March 31, 2016				As of December 31, 2015
	Carrying Value		Fair Value		Carrying Value		Fair Value
Long-term debt	$	4,594	$	5,280	$	4,597	$	5,051

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(9)    Commitments and Contingencies

MidAmerican Funding is party to a variety of legal actions arising out of the normal course of business. Plaintiffs occasionally seek punitive or exemplary damages. MidAmerican Funding does not believe that such normal and routine litigation will have a material impact on its consolidated financial results.

Refer to Note 9 of MidAmerican Energy's Notes to Financial Statements.

(10) Components of Accumulated Other Comprehensive Income (Loss), Net

Refer to Note 10 of MidAmerican Energy's Notes to Financial Statements.

(11)    Segment Information

MidAmerican Funding has identified two reportable segments: regulated electric and regulated gas. The previously reported nonregulated energy segment consisted substantially of MidAmerican Energy's unregulated retail services business, which was transferred to a subsidiary of BHE and is excluded from the information presented below. Refer to Note 3 for further discussion. The regulated electric segment derives most of its revenue from regulated retail sales of electricity to residential, commercial, and industrial customers and from wholesale sales. The regulated gas segment derives most of its revenue from regulated retail sales of natural gas to residential, commercial, and industrial customers and also obtains revenue by transporting gas owned by others through its distribution system. Pricing for regulated electric and regulated gas sales are established separately by regulatory agencies; therefore, management also reviews each segment separately to make decisions regarding allocation of resources and in evaluating performance. Common operating costs, interest income, interest expense and income tax expense are allocated to each segment based on certain factors, which primarily relate to the nature of the cost. "Other" in the tables below consists of the financial results and assets of nonregulated operations, MHC and MidAmerican Funding.

The following tables provide information on a reportable segment basis (in millions):

	Three-Month Periods
	Ended March 31,
	2016		2015
Operating revenue:
Regulated electric	$	399	$	426
Regulated gas	226		295
Other	1		6
Total operating revenue	$	626	$	727
Depreciation and amortization:
Regulated electric	$	99	$	90
Regulated gas	11		10
Total depreciation and amortization	$	110	$	100
Operating income:
Regulated electric	$	57	$	53
Regulated gas	43		47
Other	—		1
Total operating income	$	100	$	101

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	As of
	March 31, 2016		December 31, 2015
Total assets(1):
Regulated electric	$	14,206	$	14,161
Regulated gas	1,278		1,330
Other	17		183
Total assets	$	15,501	$	15,674

(1) Total assets by reportable segment reflect the assignment of goodwill to applicable reporting units. Other total assets for December 31, 2015, includes amounts for MidAmerican Energy's unregulated retail services business transferred to a subsidiary of BHE.

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Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations

MidAmerican Funding is an Iowa limited liability company whose sole member is BHE. MidAmerican Funding owns all of the outstanding common stock of MHC Inc., which owns all of the common stock of MidAmerican Energy, Midwest Capital Group, Inc. and MEC Construction Services Co. MidAmerican Energy is a public utility company headquartered in Des Moines, Iowa. MHC Inc., MidAmerican Funding and BHE are also headquartered in Des Moines, Iowa.

The following is management's discussion and analysis of certain significant factors that have affected the consolidated financial condition and results of operations of MidAmerican Funding and its subsidiaries and MidAmerican Energy as presented in this joint filing. Information in Management's Discussion and Analysis related to MidAmerican Energy, whether or not segregated, also relates to MidAmerican Funding. Information related to other subsidiaries of MidAmerican Funding pertains only to the discussion of the financial condition and results of operations of MidAmerican Funding. Where necessary, discussions have been segregated under the heading "MidAmerican Funding" to allow the reader to identify information applicable only to MidAmerican Funding. Explanations include management's best estimate of the impact of weather, customer growth and other factors. This discussion should be read in conjunction with the historical unaudited Financial Statements and Notes to Financial Statements in Part I, Item 1 of this Form 10-Q. Refer to Note 3 of those Notes to Financial Statements for a discussion of the transfer of MidAmerican Energy's unregulated retail services business to a subsidiary of BHE on January 1, 2016. MidAmerican Energy's and MidAmerican Funding's actual results in the future could differ significantly from the historical results.

Results of Operations for the First Quarter of 2016 and 2015

Overview

MidAmerican Energy -

MidAmerican Energy's income from continuing operations for the first quarter of 2016 was $76 million, a decrease of $14 million, or 16%, compared to 2015 due to higher depreciation and amortization of $10 million due to wind-powered generation and other plant placed in service, lower recognized production tax credits of $8 million, higher interest expense of $5 million due to the issuance of first mortgage bonds in October 2015, lower regulated natural gas margins of $3 million due to warmer winter temperatures, partially offset by lower fossil-fueled generation maintenance of $4 million, lower electric distribution operations and maintenance costs of $4 million and higher regulated electric margins of $3 million. Regulated electric margins reflect lower energy costs, higher retail rates in Iowa and higher transmission revenue, partially offset by lower recoveries through bill riders, lower wholesale revenue and lower retail sales volumes.

MidAmerican Funding -

MidAmerican Funding's income from continuing operations for the first quarter of 2016 was $73 million, a decrease of $22 million, or 23%, compared to 2015. In addition to the changes in MidAmerican Energy's earnings discussed above, MidAmerican Funding recognized an $8 million after-tax gain on the sale of an investment in a generating facility lease in the first quarter of 2015.

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Regulated Electric Gross Margin

A comparison of key operating results related to regulated electric gross margin is as follows:

	First Quarter
	2016		2015			Change
Gross margin (in millions):
Operating revenue	$	399	$	426		$	(27	)	(6	)%
Cost of fuel, energy and capacity	92		122			(30		)	(25	)
Gross margin	$	307	$	304		$	3		1
Electricity Sales (GWh):
Residential	1,632		1,743			(111		)	(6	)%
Small general service	948		996			(48		)	(5	)
Large general service	2,820		2,692			128			5
Other	401		400			1			—
Total retail	5,801		5,831			(30		)	(1	)
Wholesale	2,018		2,850			(832		)	(29	)
Total sales	7,819		8,681			(862		)	(10	)
Average number of retail customers (in thousands)	758		750			8			1	%
Average revenue per MWh:
Retail	$	59.01	$	61.25		$	(2.24	)	(4	)%
Wholesale	$	19.07	$	19.49		$	(0.42	)	(2	)%
Heating degree days	2,842		3,329			(487		)	(15	)%
Sources of energy (GWh)(1):
Coal	2,911		4,562			(1,651		)	(36	)%
Nuclear	936		876			60			7
Natural gas	28		(5		)	33			*
Wind and other(2)	3,131		2,641			490			19
Total energy generated	7,006		8,074			(1,068		)	(13	)
Energy purchased	966		693			273			39
Total	7,972		8,767			(795		)	(9	)

* Not meaningful.

(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 renewable portfolio standards or other regulatory requirements or (b) sold to third parties in the form of renewable energy credits or other environmental commodities.

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Regulated electric gross margin increased $3 million for the first quarter of 2016 compared to 2015 primarily due to:

(1) Higher wholesale gross margin of $4 million due to higher margins per unit due to greater wind-powered generation available for wholesale purposes and lower coal-fueled generation and prices;

(2) Higher Multi-Value Projects ("MVPs") transmission revenue of $4 million, which is expected to increase as projects are constructed over the next two years; partially offset by

(3) Lower retail gross margin of $5 million due to -

• a decrease of $20 million from lower recoveries through bill riders;

• a decrease of $6 million from the impact of temperatures;

• an increase of $10 million from higher electric rates in Iowa effective January 1, 2016;

• an increase of $9 million from lower retail energy costs primarily due to a lower average cost of fuel for generation and lower purchased power costs; and

• an increase of $2 million primarily from non-weather-related usage factors.

Regulated Gas Gross Margin

A comparison of key operating results related to regulated gas gross margin is as follows:

	First Quarter
	2016		2015		Change
Gross margin (in millions):
Operating revenue	$	226	$	295	$	(69	)	(23)	%
Cost of gas sold	135		201		(66		)	(33	)
Gross margin	$	91	$	94	$	(3	)	(3	)
Natural gas throughput (000's Dth):
Residential	22,328		25,031		(2,703		)	(11)	%
Small general service	10,822		12,108		(1,286		)	(11	)
Large general service	1,595		1,543		52			3
Other	19		22		(3		)	(14	)
Total retail sales	34,764		38,704		(3,940		)	(10	)
Wholesale sales	11,783		12,317		(534		)	(4	)
Total sales	46,547		51,021		(4,474		)	(9	)
Gas transportation service	24,065		23,969		96			—
Total gas throughput	70,612		74,990		(4,378		)	(6	)
Average number of retail customers (in thousands)	742		734		8			1	%
Average revenue per retail Dth sold	$	5.55	$	6.35	$	(0.80	)	(13)	%
Average cost of natural gas per retail Dth sold	$	3.22	$	4.18	$	(0.96	)	(23)	%
Combined retail and wholesale average cost of natural gas per Dth sold	$	2.90	$	3.93	$	(1.03	)	(26)	%
Heating degree days	2,972		3,448		(476		)	(14)	%

Regulated gas revenue includes purchased gas adjustment clauses through which MidAmerican Energy is allowed to recover the cost of gas sold from its retail gas utility customers. Consequently, fluctuations in the cost of gas sold do not directly affect gross margin or net income because regulated gas revenue reflects comparable fluctuations through the purchased gas adjustment clauses. For the first quarter of 2016, MidAmerican Energy's combined retail and wholesale average per-unit cost of gas sold decreased 26%, resulting in a decrease of $48 million in gas revenue and cost of gas sold compared to 2015.

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Regulated gas gross margin decreased $3 million for the first quarter of 2016 compared to 2015 due to $6 million from lower retail sales volumes reflecting warmer winter temperatures in 2016, partially offset by increases due to non-weather-related usage factors and higher DSM recoveries.

Operating Costs and Expenses

Operations and maintenance decreased $10 million for the first quarter of 2016 compared to 2015 due to $4 million of lower fossil-fueled generation maintenance primarily from planned major outages in 2015, $4 million of lower electric distribution operations and maintenance, and lower DSM program costs, partially offset by higher transmission operations costs from the Midcontinent Independent System Operator, Inc. ("MISO"). DSM program costs and MISO transmission costs are recovered through bill riders.

Depreciation and amortization increased $10 million for the first quarter of 2016 compared to 2015 due to utility plant additions, including wind-powered generating facilities placed in service in the second half of 2015.

Other Income and (Expense)

MidAmerican Energy -

Interest expense increased $5 million for the first quarter of 2016 compared to 2015 due to higher interest expense from the issuance of $650 million of first mortgage bonds in October 2015, partially offset by the payment of a $426 million turbine purchase obligation in December 2015.

Allowance for borrowed and equity funds decreased $2 million for the first quarter of 2016 compared to 2015 primarily due to lower construction work-in-progress balances related to wind-powered generation.

MidAmerican Funding -

In addition to the fluctuations discussed above for MidAmerican Energy, MidAmerican Funding's other, net for the first quarter of 2015 reflects a $13 million pre-tax gain on the sale of an investment in a generating facility lease in 2015.

Income Tax Benefit

MidAmerican Energy -

MidAmerican Energy's income tax benefit on continuing operations decreased $7 million for the first quarter of 2016 compared to 2015, and the effective tax rate was (29)% for 2016 and (36)% for 2015. The change in the effective tax rate for the first quarter of 2016 was primarily due to a decrease in recognized production tax credits.

Production tax credits are recognized in earnings for interim periods based on the application of an estimated annual effective tax rate to pretax earnings. Federal renewable electricity production tax credits are earned as energy from qualifying wind-powered generating facilities is produced and sold and are based on a per-kilowatt hour rate pursuant to the applicable federal income tax law. Wind-powered generating facilities are eligible for the credits for 10 years from the date the qualifying generating facilities were placed in service. Production tax credits recognized in the first quarter of 2016 were $33 million, or $8 million lower than the first quarter of 2015, while production tax credits earned in the first quarter of 2016 were $67 million, or $9 million higher than the first quarter of 2015 primarily due to wind-powered generation placed in service in late 2015. The difference between production tax credits recognized and earned of $34 million as of March 31, 2016, will be recorded to earnings over the remainder of 2016.

MidAmerican Funding -

MidAmerican Funding's income tax benefit on continuing operations decreased $2 million for the first quarter of 2016 compared to 2015, and the effective tax rate was (35)% for 2016 and (28)% for 2015. The change in the effective tax rate was principally due to the factors discussed for MidAmerican Energy.

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Liquidity and Capital Resources

As of March 31, 2016, MidAmerican Energy's total net liquidity was $346 million consisting of $1 million of cash and cash equivalents and $605 million of credit facilities reduced by $190 million of the credit facilities reserved to support MidAmerican Energy's variable-rate tax-exempt bond obligations and $70 million of short-term debt. As of March 31, 2016, MidAmerican Funding's total net liquidity was $351 million, including $1 million of additional cash and cash equivalents and MHC Inc.'s $4 million credit facility.

Operating Activities

MidAmerican Energy's net cash flows from operating activities for the three-month periods ended March 31, 2016 and 2015, were $172 million and $206 million, respectively. MidAmerican Funding's net cash flows from operating activities for the three-month periods ended March 31, 2016 and 2015, were $163 million and $197 million, respectively. The decreases were predominantly due to an increase in coal inventory in 2016, the timing of DSM expenditures and recoveries and higher collateral requirements related to derivative positions, partially offset by the net impact of payables and receivables.

In December 2015, the Protecting Americans from Tax Hikes Act of 2015 ("PATH") was signed into law, extending bonus depreciation for qualifying property acquired and placed in service before January 1, 2020 (bonus depreciation rates will be 50% for 2015-2017, 40% in 2018, and 30% in 2019), with an additional year for certain longer lived assets. Production tax credits were extended and phased-out for wind power and other forms of non-solar renewable energy projects that begin construction before the end of 2019. Production tax credits are maintained at the following levels for construction projects whose construction begins before the end of the respective year as follows: at full value for 2016, at 80% of present value for 2017, at 60% of present value for 2018, and 40% of present value for 2019. As a result of PATH, MidAmerican Energy's cash flows from operations are expected to benefit in 2016 and beyond due to bonus depreciation on qualifying assets placed in service and for production tax credits earned on qualifying wind projects.

Investing Activities

MidAmerican Energy's net cash flows from investing activities for the three-month periods ended March 31, 2016 and 2015, were $(340) million and $(250) million, respectively. MidAmerican Funding's net cash flows from investing activities for the three-month periods ended March 31, 2016 and 2015, were $(339) million and $(237) million, respectively. Net cash flows from investing activities consist almost entirely of utility construction expenditures, which increased for the first three months of 2016 compared to 2015 due to higher expenditures for wind-powered generation construction. Purchases and proceeds related to available-for-sale securities primarily consist of activity within the Quad Cities Generating Station nuclear decommissioning trust. MidAmerican Funding received $13 million in 2015 related to the sale of an investment in a generating facility lease.

Financing Activities

MidAmerican Energy's net cash flows from financing activities for the three-month periods ended March 31, 2016 and 2015 were $66 million and $15 million, respectively. MidAmerican Funding's net cash flows from financing activities for the three-month periods ended March 31, 2016 and 2015, were $75 million and $11 million, respectively. MidAmerican Energy received $70 million and $15 million in 2016 and 2015, respectively, by issuing commercial paper. MidAmerican Funding received $9 million in 2016 and made payments of $4 million in 2015 through its note payable with BHE.

Debt Authorizations and Related Matters

MidAmerican Energy has authority from the FERC to issue through June 30, 2016, commercial paper and bank notes aggregating $605 million at interest rates not to exceed the applicable London Interbank Offered Rate ("LIBOR") plus a spread of up to 400 basis points. MidAmerican Energy has a $600 million unsecured credit facility expiring in March 2018. MidAmerican Energy may request that the banks extend the credit facility up to two years. The credit facility, which supports MidAmerican Energy's commercial paper program and its variable-rate tax-exempt bond obligations and provides for the issuance of letters of credit, has a variable interest rate based on LIBOR or a base rate, at MidAmerican Energy's option, plus a spread that varies based on MidAmerican Energy's credit ratings for senior unsecured long-term debt securities. Additionally, MidAmerican Energy has a $5 million unsecured credit facility for general corporate purposes.

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MidAmerican Energy currently has an effective registration statement with the United States Securities and Exchange Commission to issue an indeterminate amount of long-term debt securities through September 16, 2018. Additionally, MidAmerican Energy has authorization from the FERC to issue through March 31, 2017, long-term securities totaling up to $1.05 billion at interest rates not to exceed the applicable United States Treasury rate plus a spread of 175 basis points and from the Illinois Commerce Commission to issue up to an aggregate of $900 million of additional long-term debt securities, of which $150 million expires December 9, 2016, and $750 million expires September 22, 2018.

In conjunction with the March 1999 merger, MidAmerican Energy committed to the IUB to use commercially reasonable efforts to maintain an investment grade rating on its long-term debt and to maintain its common equity level above 42% of total capitalization unless circumstances beyond its control result in the common equity level decreasing to below 39% of total capitalization. MidAmerican Energy must seek the approval of the IUB of a reasonable utility capital structure if MidAmerican Energy's common equity level decreases below 42% of total capitalization, unless the decrease is beyond the control of MidAmerican Energy. MidAmerican Energy is also required to seek the approval of the IUB if MidAmerican Energy's equity level decreases to below 39%, even if the decrease is due to circumstances beyond the control of MidAmerican Energy. If MidAmerican Energy's common equity level were to drop below the required thresholds, MidAmerican Energy's ability to issue debt could be restricted. As of March 31, 2016, MidAmerican Energy's common equity ratio was 52% computed on a basis consistent with its commitment.

Future Uses of Cash

MidAmerican Energy and MidAmerican Funding have available a variety of sources of liquidity and capital resources, both internal and external, including net cash flows from operating activities, public and private debt offerings, the issuance of commercial paper, the use of unsecured revolving credit facilities, and other sources. These sources are expected to provide funds required for current operations, capital expenditures, debt retirements and other capital requirements. The availability and terms under which MidAmerican Energy and MidAmerican Funding have access to external financing depends on a variety of factors, including their credit ratings, investors' judgment of risk and conditions in the overall capital markets, including the condition of the utility industry.

Utility Construction Expenditures

MidAmerican Energy's primary need for capital is utility construction expenditures. Capital expenditure needs are reviewed regularly by management and may change significantly as a result of these reviews, which may consider, among other factors, changes in environmental and other rules and regulations; impacts to customers' rates; outcomes of regulatory proceedings; changes in income tax laws; general business conditions; load projections; system reliability standards; the cost and efficiency of construction labor, equipment and materials; commodity prices; and the cost and availability of capital.

MidAmerican Energy's forecast utility construction expenditures, which exclude amounts for non-cash equity AFUDC and other non-cash items, are approximately $1.1 billion for 2016 and include:

• $660 million primarily for the construction of 599 MW (nominal ratings) of wind-powered generating facilities expected to be placed in service in 2016, of which 48 MW (nominal ratings) had been placed in service as of March 31, 2016.

• $124 million for transmission MVPs investments. MidAmerican Energy has approval from the Midcontinent Independent System Operator, Inc. for the construction of four MVPs located in Iowa and Illinois, which will add approximately 245 miles of 345 kV transmission line to MidAmerican Energy's transmission system, with remaining expenditures predominantly in 2016.

• Remaining costs primarily relate to routine expenditures for distribution, generation, transmission and other infrastructure needed to serve existing and expected demand.

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MidAmerican Energy Wind

In April 2016, MidAmerican Energy filed with the IUB an application for ratemaking principles related to the 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 filing, which is subject to IUB approval, establishes a cost cap of $3.6 billion, including AFUDC, and provides for a fixed rate of return on equity of 11.5% 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 filing proposes modifications to the revenue sharing mechanism currently in effect. The proposed sharing mechanism would be effective in 2018 and would 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 proposed change in revenue sharing, MidAmerican Energy would share 100% of the revenue in excess of this trigger with customers. Such revenue sharing would reduce coal and nuclear generation rate base, which is intended to mitigate future base rate increases. MidAmerican Energy has requested IUB approval by the end of the third quarter of 2016. If approved by the IUB, MidAmerican Energy expects to incur approximately $300 million of additional capital expenditures in 2016, which are not reflected in the current 2016 forecast.

Contractual Obligations

As of March 31, 2016, there have been no material changes outside the normal course of business in MidAmerican Energy's and MidAmerican Funding's contractual obligations from the information provided in Item 7 of their Annual Report on Form 10‑K for the year ended December 31, 2015.

Quad Cities Station Operating Status

Exelon Generation, the operator of Quad Cities Station of which MidAmerican Energy has a 25% ownership interest, has announced on May 6, 2016 its intention to shut down Quad Cities Station on June 1, 2018 if Illinois does not pass adequate legislation by May 31, 2016 or if Quad Cities Station does not clear the 2019-2020 PJM Interconnection, L.L.C. capacity auction, the results of which are expected to be available by May 24, 2016. MidAmerican Energy has expressed to Exelon Generation its desire for the continued operation of the facility through the end of its operating license in 2032. Actions by Exelon Generation to retire Quad Cities Station before the end of its operating license would require an evaluation of MidAmerican Energy's legal rights pursuant to the Quad Cities Station agreements with Exelon Generation. In addition, the carrying value and classification of assets and liabilities related to Quad Cities Station on MidAmerican Energy's balance sheets would need to be evaluated, and a determination made of the sufficiency of the nuclear decommissioning trust fund to fund decommissioning costs at an earlier retirement date. If the trust fund is determined to be deficient, MidAmerican Energy may be required to contribute additional assets to the trust fund or directly pay certain decommissioning costs.

The following significant assets and liabilities associated with Quad Cities Station were included on MidAmerican Energy's balance sheet as of March 31, 2016 (in millions):

Assets:
Net plant in service, including nuclear fuel	$	326
Construction work in progress	10
Inventory	17
Regulatory assets	4
Liabilities:
Asset retirement obligation(1)	293

(1) The Quad Cities Station asset retirement obligation assumes a 2032 closure. MidAmerican Energy’s nuclear decommissioning trust fund established for the settlement of the Quad Cities Station asset retirement obligation totaled $436 million and an associated regulatory liability for the excess of the trust fund over the asset retirement obligation totaled $143 million as of March 31, 2016.

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Environmental Laws and Regulations

MidAmerican Energy is subject to federal, state and local laws and regulations regarding air and water quality, emissions performance standards, climate change, coal combustion byproduct disposal, hazardous and solid waste disposal, protected species and other environmental matters that have the potential to impact its current and future operations. In addition to imposing continuing compliance obligations and capital expenditure requirements, these laws and regulations provide regulators with the authority to levy substantial penalties for noncompliance including fines, injunctive relief and other sanctions. These laws and regulations are administered by the EPA and various state and local agencies. All such laws and regulations are subject to a range of interpretation, which may ultimately be resolved by the courts. Environmental laws and regulations continue to evolve, and MidAmerican Energy is unable to predict the impact of the changing laws and regulations on its operations and consolidated financial results. MidAmerican Energy believes it is in material compliance with all applicable laws and regulations. Refer to "Liquidity and Capital Resources" for discussion of MidAmerican Energy's forecast environmental-related capital expenditures.

Refer to "Environmental Laws and Regulations" in Berkshire Hathaway Energy's Part I, Item 2 of this Form 10-Q for additional information regarding environmental laws and regulations.

New Accounting Pronouncements

For a discussion of new accounting pronouncements affecting MidAmerican Energy and MidAmerican Funding, refer to Note 2 of Notes to Consolidated Financial Statements in Part I, Item 1 of this Form 10-Q.

Critical Accounting Estimates

Certain accounting measurements require management to make estimates and judgments concerning transactions that will be settled several years in the future. Amounts recognized on the Financial Statements based on such estimates involve numerous assumptions subject to varying and potentially significant degrees of judgment and uncertainty and will likely change in the future as additional information becomes available. Estimates are used for, but not limited to, the accounting for the effects of certain types of regulation, derivatives, impairment of goodwill and long-lived assets, pension and other postretirement benefits, income taxes and revenue recognition - unbilled revenue. For additional discussion of MidAmerican Energy's and MidAmerican Funding's critical accounting estimates, see Item 7 of their Annual Report on Form 10-K for the year ended December 31, 2015. There have been no significant changes in MidAmerican Energy's and MidAmerican Funding's assumptions regarding critical accounting estimates since December 31, 2015.

101

Nevada Power Company and its subsidiaries

Consolidated Financial Section

102

PART I

Item 1. Financial Statements

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and Shareholder of

Nevada Power Company

Las Vegas, Nevada

We have reviewed the accompanying consolidated balance sheet of Nevada Power Company and subsidiaries ("Nevada Power") as of March 31, 2016, and the related consolidated statements of operations, changes in shareholder's equity and cash flows for the three-month periods ended March 31, 2016 and 2015. These interim financial statements are the responsibility of Nevada Power's management.

We conducted our reviews in accordance with the standards of the Public Company Accounting Oversight Board (United States). A review of interim financial information consists principally of applying analytical procedures and making inquiries of persons responsible for financial and accounting matters. It is substantially less in scope than an audit conducted in accordance with the standards of the Public Company Accounting Oversight Board (United States), the objective of which is the expression of an opinion regarding the financial statements taken as a whole. Accordingly, we do not express such an opinion.

Based on our reviews, we are not aware of any material modifications that should be made to such consolidated interim financial statements for them to be in conformity with accounting principles generally accepted in the United States of America.

We have previously audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the consolidated balance sheet of Nevada Power Company and subsidiaries as of December 31, 2015, and the related consolidated statements of operations, changes in shareholder's equity, and cash flows for the year then ended (not presented herein); and in our report dated February 26, 2016, we expressed an unqualified opinion on those consolidated financial statements. In our opinion, the information set forth in the accompanying consolidated balance sheet as of December 31, 2015 is fairly stated, in all material respects, in relation to the consolidated balance sheet from which it has been derived.

/s/ Deloitte & Touche LLP

Las Vegas, Nevada

May 6, 2016

103

NEVADA POWER COMPANY AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS (Unaudited)

(Amounts in millions, except share data)

	As of
	March 31,			December 31,
	2016			2015
ASSETS
Current assets:
Cash and cash equivalents	$	347		$	536
Accounts receivable, net	205			265
Inventories	80			80
Other current assets	51			46
Total current assets	683			927
Property, plant and equipment, net	6,996			6,996
Regulatory assets	1,051			1,057
Other assets	39			37
Total assets	$	8,769		$	9,017
LIABILITIES AND SHAREHOLDER'S EQUITY
Current liabilities:
Accounts payable	$	179		$	214
Accrued interest	38			54
Accrued property, income and other taxes	29			30
Regulatory liabilities	181			173
Current portion of long-term debt and financial and capital lease obligations	13			225
Customer deposits	58			58
Other current liabilities	38			28
Total current liabilities	536			782
Long-term debt and financial and capital lease obligations	3,058			3,060
Regulatory liabilities	306			304
Deferred income taxes	1,407			1,405
Other long-term liabilities	296			303
Total liabilities	5,603			5,854
Commitments and contingencies (Note 8)
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	861			858
Accumulated other comprehensive loss, net	(3		)	(3		)
Total shareholder's equity	3,166			3,163
Total liabilities and shareholder's equity	$	8,769		$	9,017
The accompanying notes are an integral part of the consolidated financial statements.

104

NEVADA POWER COMPANY AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF OPERATIONS (Unaudited)

(Amounts in millions)

	Three-Month Periods
	Ended March 31,
	2016			2015
Operating revenue	$	399		$	459
Operating costs and expenses:
Cost of fuel, energy and capacity	168			226
Operating and maintenance	99			76
Depreciation and amortization	75			74
Property and other taxes	11			9
Total operating costs and expenses	353			385
Operating income	46			74
Other income (expense):
Interest expense	(48		)	(46		)
Allowance for borrowed funds	1			1
Allowance for equity funds	1			1
Other, net	5			7
Total other income (expense)	(41		)	(37		)
Income before income tax expense	5			37
Income tax expense	2			13
Net income	$	3		$	24
The accompanying notes are an integral part of these consolidated financial statements.

105

NEVADA POWER COMPANY AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CHANGES IN SHAREHOLDER'S EQUITY (Unaudited)

(Amounts in millions, except shares)

								Accumulated
				Other				Other			Total
	Common Stock			Paid-in		Retained		Comprehensive			Shareholder's
	Shares	Amount		Capital		Earnings		Loss, Net			Equity
Balance, December 31, 2014	1,000	$	—	$	2,308	$	583	$	(3	)	$	2,888
Net income	—	—		—		24		—			24
Balance, March 31, 2015	1,000	$	—	$	2,308	$	607	$	(3	)	$	2,912
Balance, December 31, 2015	1,000	$	—	$	2,308	$	858	$	(3	)	$	3,163
Net income	—	—		—		3		—			3
Balance, March 31, 2016	1,000	$	—	$	2,308	$	861	$	(3	)	$	3,166
The accompanying notes are an integral part of these consolidated financial statements.

106

NEVADA POWER COMPANY AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited)

(Amounts in millions)

	Three-Month Periods
	Ended March 31,
	2016			2015
Cash flows from operating activities:
Net income	$	3		$	24
Adjustments to reconcile net income to net cash flows from operating activities:
Gain on nonrecurring items	—			(3		)
Depreciation and amortization	75			74
Deferred income taxes and amortization of investment tax credits	2			13
Allowance for equity funds	(1		)	(1		)
Changes in regulatory assets and liabilities	7			1
Deferred energy	23			39
Amortization of deferred energy	(14		)	16
Other, net	—			(16		)
Changes in other operating assets and liabilities:
Accounts receivable and other assets	47			(18		)
Inventories	—			(2		)
Accounts payable and other liabilities	(19		)	(35		)
Net cash flows from operating activities	123			92
Cash flows from investing activities:
Capital expenditures	(98		)	(63		)
Proceeds from sale of assets	—			4
Other, net	—			10
Net cash flows from investing activities	(98		)	(49		)
Cash flows from financing activities:
Repayments of long-term debt and financial and capital lease obligations	(214		)	(252		)
Net proceeds from short-term debt	—			30
Net cash flows from financing activities	(214		)	(222		)
Net change in cash and cash equivalents	(189		)	(179		)
Cash and cash equivalents at beginning of period	536			220
Cash and cash equivalents at end of period	$	347		$	41
The accompanying notes are an integral part of these consolidated financial statements.

107

NEVADA POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

(1)    Organization and Operations

Nevada Power Company, together with its subsidiaries ("Nevada Power"), is a wholly owned subsidiary of NV Energy, Inc. ("NV Energy"), a holding company that also owns Sierra Pacific Power Company ("Sierra Pacific") and certain other subsidiaries. Nevada Power is a United States regulated electric utility company serving retail customers, including residential, commercial and industrial customers, primarily in the Las Vegas, North Las Vegas, Henderson and adjoining areas. NV Energy is an indirect wholly owned subsidiary of Berkshire Hathaway Energy Company ("BHE"). BHE is a holding company based in Des Moines, Iowa that owns subsidiaries principally engaged in energy businesses. BHE is a consolidated subsidiary of Berkshire Hathaway Inc. ("Berkshire Hathaway").

The unaudited Consolidated Financial Statements have been prepared in accordance with accounting principles generally accepted in the United States of America ("GAAP") for interim financial information and the United States Securities and Exchange Commission's rules and regulations for Form 10-Q and Article 10 of Regulation S-X. Accordingly, they do not include all of the disclosures required by GAAP for annual financial statements. Management believes the unaudited Consolidated Financial Statements contain all adjustments (consisting only of normal recurring adjustments) considered necessary for the fair presentation of the unaudited Consolidated Financial Statements as of March 31, 2016 and for the three-month periods ended March 31, 2016 and 2015. The Consolidated Statements of Comprehensive Income have been omitted as net income equals comprehensive income for the three-month periods ended March 31, 2016 and 2015. The results of operations for the three-month period ended March 31, 2016 are not necessarily indicative of the results to be expected for the full year.

The preparation of the unaudited Consolidated Financial Statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities at the date of the unaudited Consolidated Financial Statements and the reported amounts of revenue and expenses during the period. Actual results may differ from the estimates used in preparing the unaudited Consolidated Financial Statements. Note 2 of Nevada Power's Item 8 Notes to Consolidated Financial Statements included in BHE's Annual Report on Form 10-K for the year ended December 31, 2015 describes the most significant accounting policies used in the preparation of the unaudited Consolidated Financial Statements. There have been no significant changes in Nevada Power's assumptions regarding significant accounting estimates and policies during the three-month period ended March 31, 2016.

(2)    New Accounting Pronouncements

In February 2016, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") No. 2016-02, which creates FASB Accounting Standards Codification ("ASC") Topic 842, "Leases" and supersedes Topic 840 "Leases." This guidance increases transparency and comparability among entities by recording lease assets and lease liabilities on the balance sheet and disclosing key information about leasing arrangements. A lessee should recognize in the balance sheet a liability to make lease payments (the lease liability) and a right-of-use asset representing its right to use the underlying asset for the lease term. The recognition, measurement, and presentation of expenses and cash flows arising from a lease by a lessee have not significantly changed from previous guidance. This guidance is effective for interim and annual reporting periods beginning after December 15, 2018, with early adoption permitted, and is required to be adopted using a modified retrospective approach. Nevada Power is currently evaluating the impact of adopting this guidance on its Consolidated Financial Statements and disclosures included within Notes to Consolidated Financial Statements.

In May 2014, the FASB issued ASU No. 2014-09, which creates FASB ASC Topic 606, "Revenue from Contracts with Customers" and supersedes ASC Topic 605, "Revenue Recognition." The guidance replaces industry-specific guidance and establishes a single five-step model to identify and recognize revenue. The core principle of the guidance is that an entity should recognize revenue upon transfer of control of promised goods or services to customers in an amount that reflects the consideration to which an entity expects to be entitled in exchange for those goods or services. Additionally, the guidance requires the entity to disclose further quantitative and qualitative information regarding the nature and amount of revenues arising from contracts with customers, as well as other information about the significant judgments and estimates used in recognizing revenues from contracts with customers. In August 2015, the FASB issued ASU No. 2015-14, which defers the effective date of ASU No. 2014-09 one year to interim and annual reporting periods beginning after December 15, 2017. This guidance may be adopted retrospectively or under a modified retrospective method where the cumulative effect is recognized at the date of initial application. Nevada Power is currently evaluating the impact of adopting this guidance on its Consolidated Financial Statements and disclosures included within Notes to Consolidated Financial Statements.

108

(3)    Property, Plant and Equipment, Net

Property, plant and equipment, net consists of the following (in millions):

		As of
	Depreciable Life	March 31,			December 31,
		2016			2015
Utility plant:
Generation	25 - 80 years	$	4,228		$	4,212
Distribution	20 - 65 years	3,148			3,118
Transmission	45 - 65 years	1,796			1,788
General and intangible plant	5 - 65 years	721			694
Utility plant		9,893			9,812
Accumulated depreciation and amortization		(3,034		)	(2,971		)
Utility plant, net		6,859			6,841
Other non-regulated, net of accumulated depreciation and amortization	5 - 65 years	2			2
Plant, net		6,861			6,843
Construction work-in-progress		135			153
Property, plant and equipment, net		$	6,996		$	6,996

(4)    Regulatory Matters

Deferred Energy

Nevada statutes permit regulated utilities to adopt deferred energy accounting procedures. The intent of these procedures is to ease the effect on customers of fluctuations in the cost of purchased natural gas, fuel and electricity and are subject to annual prudency review by the Public Utilities Commission of Nevada ("PUCN").

Under deferred energy accounting, to the extent actual fuel and purchased power costs exceed fuel and purchased power costs recoverable through current rates that excess is not recorded as a current expense on the Consolidated Statements of Operations but rather is deferred and recorded as a regulatory asset on the Consolidated Balance Sheets. Conversely, a regulatory liability is recorded to the extent fuel and purchased power costs recoverable through current rates exceed actual fuel and purchased power costs. These excess amounts are reflected in quarterly adjustments to rates and recorded as cost of fuel, energy and capacity in future time periods.

(5)    Employee Benefit Plans

Nevada Power is a participant in benefit plans sponsored by NV Energy. The NV Energy Retirement Plan includes a qualified pension plan ("Qualified Pension Plan") and a supplemental executive retirement plan and a restoration plan (collectively, "Non‑Qualified Pension Plans") that provide pension benefits for eligible employees. The NV Energy Comprehensive Welfare Benefit and Cafeteria Plan provides certain postretirement health care and life insurance benefits for eligible retirees ("Other Postretirement Plans") on behalf of Nevada Power. Amounts attributable to Nevada Power were allocated from NV Energy based upon the current, or in the case of retirees, previous, employment location. Offsetting regulatory assets and liabilities have been recorded related to the amounts not yet recognized as a component of net periodic benefit costs that will be included in regulated rates. Net periodic benefit costs not included in regulated rates are included in accumulated other comprehensive loss, net.

109

Amounts payable to NV Energy are included on the Consolidated Balance Sheets and consist of the following (in millions):

	As of
	March 31,			December 31,
	2016			2015
Qualified Pension Plan -
Other long-term liabilities	$	(40	)	$	(38	)
Non-Qualified Pension Plans:
Other current liabilities	(1		)	(1		)
Other long-term liabilities	(9		)	(9		)
Other Postretirement Plans -
Other long-term liabilities	(5		)	(5		)

(6)     Risk Management and Hedging Activities

Nevada Power is exposed to the impact of market fluctuations in commodity prices and interest rates. Nevada Power is principally exposed to electricity, natural gas and coal market fluctuations primarily through Nevada Power's obligation to serve retail customer load in its regulated service territory. Nevada Power's load and generating facilities represent substantial underlying commodity positions. Exposures to commodity prices consist mainly of variations in the price of fuel required to generate electricity and wholesale electricity that is purchased and sold. Commodity prices are subject to wide price swings as supply and demand are impacted by, among many other unpredictable items, weather, market liquidity, generating facility availability, customer usage, storage, and transmission and transportation constraints. The actual cost of fuel and purchased power is recoverable through the deferred energy mechanism. Interest rate risk exists on variable-rate debt and future debt issuances. Nevada Power does not engage in proprietary trading activities.

Nevada Power has established a risk management process that is designed to identify, assess, manage, mitigate, monitor and report each of the various types of risk involved in its business. To mitigate a portion of its commodity price risk, Nevada Power uses commodity derivative contracts, which may include forwards, futures, options, swaps and other agreements, to effectively secure future supply or sell future production generally at fixed prices. Nevada Power manages its interest rate risk by limiting its exposure to variable interest rates primarily through the issuance of fixed‑rate long-term debt and by monitoring market changes in interest rates. Additionally, Nevada Power may from time to time enter into interest rate derivative contracts, such as interest rate swaps or locks, to mitigate Nevada Power's exposure to interest rate risk. Nevada Power does not hedge all of its commodity price and interest rate risks, thereby exposing the unhedged portion to changes in market prices.

There have been no significant changes in Nevada Power's accounting policies related to derivatives. Refer to Note 7 for additional information on derivative contracts.

The following table, which excludes contracts that have been designated as normal under the normal purchases or normal sales exception afforded by GAAP, summarizes the fair value of Nevada Power's derivative contracts, on a gross basis, and reconciles those amounts to the amounts presented on a net basis on the Consolidated Balance Sheets (in millions):

	Other			Other
	Current			Long-term
	Liabilities			Liabilities			Total
As of March 31, 2016
Commodity liabilities(1)	$	(9	)	$	(13	)	$	(22	)
As of December 31, 2015
Commodity liabilities(1)	$	(8	)	$	(14	)	$	(22	)

(1) Nevada Power's commodity derivatives not designated as hedging contracts are included in regulated rates and as of March 31, 2016 and December 31, 2015, a regulatory asset of $22 million was recorded related to the derivative liability of $22 million.

110

Derivative Contract Volumes

The following table summarizes the net notional amounts of outstanding derivative contracts with indexed and fixed price terms that comprise the mark-to-market values as of (in millions):

	Unit of	March 31,		December 31,
	Measure	2016		2015
Electricity sales	Megawatt hours	(2	)	(2	)
Natural gas purchases	Decatherms	169		126

Credit Risk

Nevada Power is exposed to counterparty credit risk associated with wholesale energy supply and marketing activities with other utilities, energy marketing companies, financial institutions and other market participants. Credit risk may be concentrated to the extent Nevada Power's counterparties have similar economic, industry or other characteristics and due to direct and indirect relationships among the counterparties. Before entering into a transaction, Nevada Power analyzes the financial condition of each significant wholesale counterparty, establish limits on the amount of unsecured credit to be extended to each counterparty and evaluate the appropriateness of unsecured credit limits on an ongoing basis. To further mitigate wholesale counterparty credit risk, Nevada Power enters into netting and collateral arrangements that may include margining and cross-product netting agreements and obtain third-party guarantees, letters of credit and cash deposits. If required, Nevada Power exercises rights under these arrangements, including calling on the counterparty's credit support arrangement.

Collateral and Contingent Features

In accordance with industry practice, certain wholesale derivative contracts contain credit support provisions that in part base certain collateral requirements on credit ratings for unsecured debt as reported by one or more of the three recognized credit rating agencies. These derivative contracts may either specifically provide rights to demand cash or other security in the event of a credit rating downgrade ("credit-risk-related contingent features") or provide the right for counterparties to demand "adequate assurance," in the event of a material adverse change in creditworthiness. These rights can vary by contract and by counterparty. As of March 31, 2016, credit ratings from the three recognized credit rating agencies were investment grade.

The aggregate fair value of Nevada Power's derivative contracts in liability positions with specific credit-risk-related contingent features was $4 million and $3 million as of March 31, 2016 and December 31, 2015, respectively, which represents the amount of collateral to be posted if all credit risk related contingent features for derivative contracts in liability positions had been triggered. Nevada Power's collateral requirements could fluctuate considerably due to market price volatility, changes in credit ratings, changes in legislation or regulation or other factors.

111

(7) Fair Value Measurements

The carrying value of Nevada Power's cash, certain cash equivalents, receivables, payables, accrued liabilities and short-term borrowings approximates fair value because of the short-term maturity of these instruments. Nevada Power has various financial assets and liabilities that are measured at fair value on the Consolidated Balance Sheets using inputs from the three levels of the fair value hierarchy. A financial asset or liability classification within the hierarchy is determined based on the lowest level input that is significant to the fair value measurement. The three levels are as follows:

• 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.

The following table presents Nevada Power's assets and liabilities recognized on the Consolidated Balance Sheets and measured at fair value on a recurring basis (in millions):

	Input Levels for Fair Value Measurements
	Level 1		Level 2		Level 3			Total
As of March 31, 2016
Assets - investment funds	$	5	$	—	$	—		$	5
Liabilities - commodity derivatives	$	—	$	—	$	(22	)	$	(22	)
As of December 31, 2015
Assets - investment funds	$	5	$	—	$	—		$	5
Liabilities - commodity derivatives	$	—	$	—	$	(22	)	$	(22	)

Derivative contracts are recorded on the Consolidated Balance Sheets as either assets or liabilities and are stated at estimated fair value unless they are designated as normal purchases or normal sales and qualify for the exception afforded by GAAP. When available, the fair value of derivative contracts is estimated using unadjusted quoted prices for identical contracts in the market in which Nevada Power transacts. When quoted prices for identical contracts are not available, Nevada Power uses forward price curves. Forward price curves represent Nevada Power's estimates of the prices at which a buyer or seller could contract today for delivery or settlement at future dates. Nevada Power bases its forward price curves upon internally developed models, with internal and external fundamental data inputs. Market price quotations for certain electricity and natural gas trading hubs are not as readily obtainable due to markets that are not active. Given that limited market data exists for these contracts, Nevada Power uses forward price curves derived from internal models based on perceived pricing relationships to major trading hubs that are based on unobservable inputs. The model incorporates a mid-market pricing convention (the mid‑point price between bid and ask prices) as a practical expedient for valuing its assets and liabilities measured and reported at fair value. Interest rate swaps are valued using a financial model which utilizes observable inputs for similar instruments based primarily on market price curves. The determination of the fair value for derivative contracts not only includes counterparty risk, but also the impact of Nevada Power's nonperformance risk on its liabilities, which as of March 31, 2016 and December 31, 2015, had an immaterial impact to the fair value of its derivative contracts. As such, Nevada Power considers its derivative contracts to be valued using Level 3 inputs. Refer to Note 6 for further discussion regarding Nevada Power's risk management and hedging activities.

Nevada Power's investments in money market mutual funds and equity securities are accounted for as available-for-sale securities and are stated at fair value. When available, a readily observable quoted market price or net asset value of an identical security in an active market is used to record the fair value.

112

The following table reconciles the beginning and ending balances of Nevada Power's commodity derivative liabilities measured at fair value on a recurring basis using significant Level 3 inputs (in millions):

	Three-Month Periods
	Ended March 31,
	2016			2015
Beginning balance	$	(22	)	$	(30	)
Changes in fair value recognized in regulatory assets	(3		)	(4		)
Settlements	3			2
Ending balance	$	(22	)	$	(32	)

Nevada Power's long-term debt is carried at cost on the Consolidated Balance Sheets. The fair value of Nevada Power's long‑term debt is a Level 2 fair value measurement and has been estimated based upon quoted market prices, where available, or at the present value of future cash flows discounted at rates consistent with comparable maturities with similar credit risks. The carrying value of Nevada Power's variable-rate long-term debt approximates fair value because of the frequent repricing of these instruments at market rates. The following table presents the carrying value and estimated fair value of Nevada Power's long‑term debt (in millions):

	As of March 31, 2016				As of December 31, 2015
	Carrying		Fair		Carrying		Fair
	Value		Value		Value		Value
Long-term debt	$	2,579	$	3,141	$	2,788	$	3,240

(8) Commitments and Contingencies

Environmental Laws and Regulations

Nevada Power is subject to federal, state and local laws and regulations regarding air and water quality, renewable portfolio standards, emissions performance standards, climate change, coal combustion byproduct disposal, hazardous and solid waste disposal, protected species and other environmental matters that have the potential to impact Nevada Power's current and future operations. Nevada Power believes it is in material compliance with all applicable laws and regulations.

Senate Bill 123

In June 2013, the Nevada State Legislature passed Senate Bill No. 123 ("SB 123"), which included the retirement of coal plants and replacing the capacity with renewable and other generating facilities. In May 2014, Nevada Power filed its Emissions Reduction Capacity Replacement Plan ("ERCR Plan") in compliance with SB 123. In July 2015, Nevada Power filed an amendment to its ERCR Plan with the PUCN which was approved in September 2015. In June 2015, the Nevada State Legislature passed Assembly Bill No. 498, which modified the capacity replacement components of SB 123.

Consistent with direction provided by the PUCN, Nevada Power acquired a 272-megawatt ("MW") natural gas co-generating facility in 2014, acquired a 210-MW natural gas peaking facility in 2014, constructed a 15-MW solar photovoltaic facility in 2015 and contracted two renewable power purchase agreements with 100-MW solar photovoltaic generating facilities in 2015. In February 2016, Nevada Power solicited proposals to acquire 35 MW of nameplate renewable energy capacity to be owned by Nevada Power and solicited a long-term power purchase agreement for a minimum of 100 MW of nameplate renewable energy capacity in Nevada. These solicitations are related to Nevada Power's final steps to comply with SB 123, resulting in the retirement of 812 MW of coal-fueled generation by 2019.

Legal Matters

Nevada Power is party to a variety of legal actions arising out of the normal course of business. Plaintiffs occasionally seek punitive or exemplary damages. Nevada Power does not believe that such normal and routine litigation will have a material impact on its consolidated financial results.

113

Item 2.    Management's Discussion and Analysis of Financial Condition and Results of Operations 

General

Nevada Power's revenues and operating income are subject to fluctuations during the year due to impacts that seasonal weather, rate changes, and customer usage patterns have on demand for electric energy and resources. Nevada Power is a summer peaking utility experiencing its highest retail energy sales in response to the demand for air conditioning. The variations in energy usage due to varying weather, customer growth and other energy usage patterns, including energy efficiency and conservation measures, necessitates a continual balancing of loads and resources and purchases and sales of energy under short- and long-term energy supply contracts. As a result, the prudent management and optimization of available resources has a direct effect on the operating and financial performance of Nevada Power. Additionally, the timely recovery of purchased power, fuel costs and other costs and the ability to earn a fair return on investments through rates are essential to the operating and financial performance of Nevada Power.

The following is management's discussion and analysis of certain significant factors that have affected the consolidated financial condition and results of operations of Nevada Power during the periods included herein. Explanations include management's best estimate of the impact of weather, customer growth and other factors. This discussion should be read in conjunction with Nevada Power's historical unaudited Consolidated Financial Statements and Notes to Consolidated Financial Statements in Part I, Item 1 of this Form 10-Q. Nevada Power's actual results in the future could differ significantly from the historical results.

Results of Operations for the First Quarter of 2016 and 2015

Net income for the first quarter of 2016 was $3 million, a decrease of $21 million, or 88%, compared to 2015 due to benefits from changes in contingent liabilities in 2015, higher planned maintenance and other generating costs, lower margins from changes in usage patterns with commercial and industrial customers and lower transmission demand, a gain on the sale of an equity investment in 2015, increased taxes due to a new state commerce tax and increases in property and franchise taxes, and higher interest on deferred charges.

114

Operating revenue and cost of fuel, energy and capacity are key drivers of Nevada Power's results of operations as they encompass retail and wholesale electricity revenue and the direct costs associated with providing electricity to customers. Nevada Power believes that a discussion of gross margin, representing operating revenue less cost of fuel, energy and capacity, is therefore meaningful. A comparison of Nevada Power's key operating results is as follows:

	First Quarter
	2016		2015		Change
Gross margin (in millions):
Operating revenue	$	399	$	459	$	(60	)	(13	)	%
Cost of fuel, energy and capacity	168		226		(58		)	(26	)
Gross margin	$	231	$	233	$	(2	)	(1	)
GWh sold:
Residential	1,573		1,525		48			3		%
Commercial	984		993		(9		)	(1	)
Industrial	1,651		1,717		(66		)	(4	)
Other	49		53		(4		)	(8	)
Total retail	4,257		4,288		(31		)	(1	)
Wholesale	55		14		41			*
Total GWh sold	4,312		4,302		10			—
Average number of retail customers (in thousands):
Residential	791		776		15			2		%
Commercial	105		105		—			—
Industrial	2		2		—			—
Total	898		883		15			2
Average retail revenue per MWh	$	91.42	$	104.34	$	(12.92	)	(12	)	%
Heating degree days	790		586		204			35		%
Cooling degree days	64		148		(84		)	(57	)	%
Sources of energy (GWh)(1):
Coal	185		283		(98		)	(35	)	%
Natural gas	3,111		3,547		(436		)	(12	)
Renewables	8		—		8			*
Total energy generated	3,304		3,830		(526		)	(14	)
Energy purchased	1,232		523		709			*
Total	4,536		4,353		183			4

*     Not meaningful

(1) GWh amounts are net of energy used by the related generating facilities.

115

Gross margin decreased $2 million, or 1%, for the first quarter of 2016 compared to 2015 due to:

• $2 million in usage patterns for commercial and industrial customers and

• $1 million in lower transmission demand.

The decrease in gross margin was partially offset by:

• $1 million in higher energy efficiency program rate revenue, which is offset in operating and maintenance expense.

Operating and maintenance increased $23 million, or 30%, for the first quarter of 2016 compared to 2015 due to benefits from changes in contingent liabilities in 2015, higher planned maintenance and other generating costs and higher energy efficiency program costs, which are fully recovered in operating revenue.

Property and other taxes increased $2 million, or 22%, for the first quarter of 2016 compared to 2015 due to a new state commerce tax and increases in property and franchise taxes.

Other income (expense) is unfavorable $4 million, or 11%, for the first quarter of 2016 compared to 2015 due to a gain on the sale of an equity investment in March 2015 and higher interest on deferred charges.

Income tax expense decreased $11 million, or 85%, for the first quarter of 2016 compared to 2015. The effective tax rate was 35% for 2016 and 2015.

Liquidity and Capital Resources

As of March 31, 2016, Nevada Power's total net liquidity was $747 million consisting of $347 million in cash and cash equivalents and $400 million of revolving credit facility availability.

Operating Activities

Net cash flows from operating activities for the three-month periods ended March 31, 2016 and 2015 were $123 million and $92 million, respectively. The change was due to lower payments for fuel costs and lower interest payments, partially offset by decreased collections from customers due to lower retail rates as a result of deferred energy adjustment mechanisms.

In December 2015, the Protecting Americans from Tax Hikes Act of 2015 ("PATH") was signed into law, extending bonus depreciation for qualifying property acquired and placed in-service before January 1, 2020 (bonus depreciation rates will be 50% for 2015-2017, 40% in 2018, and 30% in 2019), with an additional year for certain longer lived assets. Investment tax credits were extended and phased-down for solar projects that are under construction before the end of 2021 (investment tax credit rates are 30% through 2019, 26% in 2020 and 22% in 2021; they revert to the statutory rate of 10% thereafter). As a result of PATH, Nevada Power's cash flows from operations are expected to benefit in 2016 and beyond due to bonus depreciation on qualifying assets placed in-service and investment tax credits (once the net operating loss is fully utilized) earned on qualifying projects.

Investing Activities

Net cash flows from investing activities for the three-month periods ended March 31, 2016 and 2015 were $(98) million and $(49) million, respectively. The change was due to increased capital maintenance expenditures and cash received for the sale of securities and an equity investment in 2015.

Financing Activities

Net cash flows from financing activities for the three-month periods ended March 31, 2016 and 2015 were $(214) million and $(222) million, respectively. The change was due to lower repayments of long-term debt, partially offset by net proceeds from short-term borrowings in 2015.

116

Ability to Issue Debt

Nevada Power's ability to issue debt is primarily impacted by its financing authority from the PUCN. As of March 31, 2016, Nevada Power has financing authority from the PUCN consisting of the ability to: (1) issue additional long-term debt securities of up to $725 million; (2) refinance up to $553 million of long-term debt securities; and (3) maintain a revolving credit facility of up to $1.3 billion. Nevada Power's revolving credit facility contains a financial maintenance covenant which Nevada Power was in compliance with as of March 31, 2016. In addition, certain financing agreements contain covenants which are currently suspended as Nevada Power's senior secured debt is rated investment grade. However, if Nevada Power's senior secured debt ratings fall below investment grade by either Moody's Investors Service or Standard & Poor's, Nevada Power would be subject to limitations under these covenants.

Future Uses of Cash

Nevada Power has available a variety of sources of liquidity and capital resources, both internal and external, including net cash flows from operating activities, public and private debt offerings, the use of its secured revolving credit facility, capital contributions and other sources. These sources are expected to provide funds required for current operations, capital expenditures, debt retirements and other capital requirements. The availability and terms under which Nevada Power has access to external financing depends on a variety of factors, including Nevada Power's credit ratings, investors' judgment of risk and conditions in the overall capital markets, including the condition of the utility industry.

Capital Expenditures

Nevada Power has significant future capital requirements. Capital expenditure needs are reviewed regularly by management and may change significantly as a result of these reviews, which may consider, among other factors, changes in environmental and other rules and regulations; impacts to customers' rates; outcomes of regulatory proceedings; changes in income tax laws; general business conditions; load projections; system reliability standards; the cost and efficiency of construction labor, equipment and materials; commodity prices; and the cost and availability of capital. Expenditures for certain assets may ultimately include acquisitions of existing assets.

Nevada Power's historical and forecast capital expenditures, each of which exclude amounts for non-cash equity AFUDC and other non-cash items are as follows (in millions):

	Three-Month Periods				Annual
	Ended March 31,				Forecast
	2015		2016		2016
Generation development	$	6	$	—	$	2
Distribution	28		26		86
Transmission system investment	6		11		32
Other	23		61		115
Total	$	63	$	98	$	235

In April 2016, Nevada Power executed an agreement to purchase a 504-MW natural gas facility. The sale is subject to certain conditions including federal and state regulatory approval. The transaction is expected to close no later than the first quarter of 2017.

Contractual Obligations

As of March 31, 2016, there have been no material changes outside the normal course of business in contractual obligations from the information provided in Item 7 of Nevada Power's Annual Report on Form 10-K for the year ended December 31, 2015.

Regulatory Matters

Nevada Power is subject to comprehensive regulation. Refer to "Regulatory Matters" in Berkshire Hathaway Energy's Part I, Item 2 of this Form 10-Q for discussion regarding Nevada Power's current regulatory matters.

117

Environmental Laws and Regulations

Nevada Power is subject to federal, state and local laws and regulations regarding air and water quality, RPS, emissions performance standards, climate change, coal combustion byproduct disposal, hazardous and solid waste disposal, protected species and other environmental matters that have the potential to impact Nevada Power's current and future operations. In addition to imposing continuing compliance obligations and capital expenditure requirements, these laws and regulations provide regulators with the authority to levy substantial penalties for noncompliance including fines, injunctive relief and other sanctions. These laws and regulations are administered by the EPA and various state and local agencies. All such laws and regulations are subject to a range of interpretation, which may ultimately be resolved by the courts. Environmental laws and regulations continue to evolve, and Nevada Power is unable to predict the impact of the changing laws and regulations on its operations and consolidated financial results. Nevada Power believes it is in material compliance with all applicable laws and regulations. Refer to "Liquidity and Capital Resources" for discussion of Nevada Power's forecasted environmental-related capital expenditures.

Refer to "Environmental Laws and Regulations" in Berkshire Hathaway Energy's Part I, Item 2 of this Form 10-Q for additional information regarding environmental laws.

New Accounting Pronouncements

For a discussion of new accounting pronouncements affecting Nevada Power, refer to Note 2 of Notes to Consolidated Financial Statements in Nevada Power's Part I, Item 1 of this Form 10-Q.

Critical Accounting Estimates

Certain accounting measurements require management to make estimates and judgments concerning transactions that will be settled several years in the future. Amounts recognized on the Consolidated Financial Statements based on such estimates involve numerous assumptions subject to varying and potentially significant degrees of judgment and uncertainty and will likely change in the future as additional information becomes available. Estimates are used for, but not limited to, the accounting for the effects of certain types of regulation, derivatives, impairment of long-lived assets, income taxes and revenue recognition - unbilled revenue. For additional discussion of Nevada Power's critical accounting estimates, see Item 7 of Nevada Power's Annual Report on Form 10‑K for the year ended December 31, 2015. There have been no significant changes in Nevada Power's assumptions regarding critical accounting estimates since December 31, 2015.

118

Sierra Pacific Power Company and its subsidiaries

Consolidated Financial Section

119

PART I

Item 1. Financial Statements

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and Shareholder of

Sierra Pacific Power Company

Las Vegas, Nevada

We have reviewed the accompanying consolidated balance sheet of Sierra Pacific Power Company and subsidiaries ("Sierra Pacific") as of March 31, 2016, and the related consolidated statements of operations, changes in shareholder's equity and cash flows for the three-month periods ended March 31, 2016 and 2015. These interim financial statements are the responsibility of Sierra Pacific's management.

We conducted our reviews in accordance with the standards of the Public Company Accounting Oversight Board (United States). A review of interim financial information consists principally of applying analytical procedures and making inquiries of persons responsible for financial and accounting matters. It is substantially less in scope than an audit conducted in accordance with the standards of the Public Company Accounting Oversight Board (United States), the objective of which is the expression of an opinion regarding the financial statements taken as a whole. Accordingly, we do not express such an opinion.

Based on our reviews, we are not aware of any material modifications that should be made to such consolidated interim financial statements for them to be in conformity with accounting principles generally accepted in the United States of America.

We have previously audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the consolidated balance sheet of Sierra Pacific Power Company and subsidiaries as of December 31, 2015, and the related consolidated statements of operations, changes in shareholder's equity, and cash flows for the year then ended (not presented herein); and in our report dated February 26, 2016, we expressed an unqualified opinion on those consolidated financial statements. In our opinion, the information set forth in the accompanying consolidated balance sheet as of December 31, 2015 is fairly stated, in all material respects, in relation to the consolidated balance sheet from which it has been derived.

/s/ Deloitte & Touche LLP

Las Vegas, Nevada

May 6, 2016

120

SIERRA PACIFIC POWER COMPANY AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS (Unaudited)

(Amounts in millions, except share data)

	As of
	March 31,			December 31,
	2016			2015
ASSETS
Current assets:
Cash and cash equivalents	$	135		$	106
Accounts receivable, net	99			124
Inventories	39			39
Other current assets	20			13
Total current assets	293			282
Property, plant and equipment, net	2,770			2,766
Regulatory assets	430			432
Other assets	7			7
Total assets	$	3,500		$	3,487
LIABILITIES AND SHAREHOLDER'S EQUITY
Current liabilities:
Accounts payable	$	97		$	127
Accrued interest	16			15
Accrued property, income and other taxes	13			13
Regulatory liabilities	90			78
Current portion of long-term debt and financial and capital lease obligations	453			453
Customer deposits	17			17
Other current liabilities	14			11
Total current liabilities	700			714
Long-term debt and financial and capital lease obligations	749			749
Regulatory liabilities	229			230
Deferred income taxes	580			570
Other long-term liabilities	149			148
Total liabilities	2,407			2,411
Commitments and contingencies (Note 8)
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	(18		)	(35		)
Total shareholder's equity	1,093			1,076
Total liabilities and shareholder's equity	$	3,500		$	3,487
The accompanying notes are an integral part of the consolidated financial statements.

121

SIERRA PACIFIC POWER COMPANY AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF OPERATIONS (Unaudited)

(Amounts in millions)

	Three-Month Periods
	Ended March 31,
	2016			2015
Operating revenue:
Electric	$	170		$	196
Natural Gas	47			50
Total operating revenue	217			246
Operating costs and expenses:
Cost of fuel, energy and capacity	70			97
Natural gas purchased for resale	30			35
Operating and maintenance	41			36
Depreciation and amortization	29			28
Property and other taxes	6			7
Total operating costs and expenses	176			203
Operating income	41			43
Other income (expense):
Interest expense	(16		)	(15		)
Allowance for equity funds	1			1
Other, net	1			1
Total other income (expense)	(14		)	(13		)
Income before income tax expense	27			30
Income tax expense	10			11
Net income	$	17		$	19
The accompanying notes are an integral part of these consolidated financial statements.

122

SIERRA PACIFIC POWER COMPANY AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CHANGES IN SHAREHOLDER'S EQUITY (Unaudited)

(Amounts in millions, except shares)

									Accumulated
				Other					Other			Total
	Common Stock			Paid-in		Accumulated			Comprehensive			Shareholder's
	Shares	Amount		Capital		Deficit			Loss, Net			Equity
Balance, December 31, 2014	1,000	$	—	$	1,111	$	(111	)	$	(2	)	$	998
Net income	—	—		—		19			—			19
Balance, March 31, 2015	1,000	$	—	$	1,111	$	(92	)	$	(2	)	$	1,017
Balance, December 31, 2015	1,000	$	—	$	1,111	$	(35	)	$	—		$	1,076
Net income	—	—		—		17			—			17
Balance, March 31, 2016	1,000	$	—	$	1,111	$	(18	)	$	—		$	1,093
The accompanying notes are an integral part of these consolidated financial statements.

123

SIERRA PACIFIC POWER COMPANY AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited)

(Amounts in millions)

	Three-Month Periods
	Ended March 31,
	2016			2015
Cash flows from operating activities:
Net income	$	17		$	19
Adjustments to reconcile net income to net cash flows from operating activities:
Depreciation and amortization	29			28
Allowance for equity funds	(1		)	—
Deferred income taxes and amortization of investment tax credits	10			11
Changes in regulatory assets and liabilities	(3		)	(4		)
Deferred energy	23			26
Amortization of deferred energy	(9		)	12
Other, net	—			(1		)
Changes in other operating assets and liabilities:
Accounts receivable and other assets	18			(11		)
Inventories	1			—
Accounts payable and other liabilities	(7		)	(4		)
Net cash flows from operating activities	78			76
Cash flows from investing activities:
Capital expenditures	(48		)	(47		)
Other, net	—			2
Net cash flows from investing activities	(48		)	(45		)
Cash flows from financing activities:
Repayments of long-term debt and financial and capital lease obligations	(1		)	—
Net cash flows from financing activities	(1		)	—
Net change in cash and cash equivalents	29			31
Cash and cash equivalents at beginning of period	106			22
Cash and cash equivalents at end of period	$	135		$	53
The accompanying notes are an integral part of these consolidated financial statements.

124

SIERRA PACIFIC POWER COMPANY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

(1)    Organization and Operations

Sierra Pacific Power Company, together with its subsidiaries ("Sierra Pacific"), is a wholly owned subsidiary of NV Energy, Inc. ("NV Energy"), a holding company that also owns Nevada Power Company ("Nevada Power") and certain other subsidiaries. Sierra Pacific is a United States regulated electric utility company serving retail customers, including residential, commercial and industrial customers and regulated retail natural gas customers primarily in northern Nevada. NV Energy is an indirect wholly owned subsidiary of Berkshire Hathaway Energy Company ("BHE"). BHE is a holding company based in Des Moines, Iowa that owns subsidiaries principally engaged in energy businesses. BHE is a consolidated subsidiary of Berkshire Hathaway Inc. ("Berkshire Hathaway").

The unaudited Consolidated Financial Statements have been prepared in accordance with accounting principles generally accepted in the United States of America ("GAAP") for interim financial information and the United States Securities and Exchange Commission's rules and regulations for Form 10-Q and Article 10 of Regulation S-X. Accordingly, they do not include all of the disclosures required by GAAP for annual financial statements. Management believes the unaudited Consolidated Financial Statements contain all adjustments (consisting only of normal recurring adjustments) considered necessary for the fair presentation of the unaudited Consolidated Financial Statements as of March 31, 2016 and for the three-month periods ended March 31, 2016 and 2015. The Consolidated Statements of Comprehensive Income have been omitted as net income equals comprehensive income for the three-month periods ended March 31, 2016 and 2015. The results of operations for the three-month period ended March 31, 2016 are not necessarily indicative of the results to be expected for the full year.

The preparation of the unaudited Consolidated Financial Statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities at the date of the unaudited Consolidated Financial Statements and the reported amounts of revenue and expenses during the period. Actual results may differ from the estimates used in preparing the unaudited Consolidated Financial Statements. Note 2 of Sierra Pacific's Item 8 Notes to Consolidated Financial Statements included in BHE's Annual Report on Form 10-K for the year ended December 31, 2015 describes the most significant accounting policies used in the preparation of the unaudited Consolidated Financial Statements. There have been no significant changes in Sierra Pacific's assumptions regarding significant accounting estimates and policies during the three-month period ended March 31, 2016.

(2)    New Accounting Pronouncements

In February 2016, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") No. 2016-02, which creates FASB Accounting Standards Codification ("ASC") Topic 842, "Leases" and supersedes Topic 840 "Leases." This guidance increases transparency and comparability among entities by recording lease assets and lease liabilities on the balance sheet and disclosing key information about leasing arrangements. A lessee should recognize in the balance sheet a liability to make lease payments (the lease liability) and a right-of-use asset representing its right to use the underlying asset for the lease term. The recognition, measurement, and presentation of expenses and cash flows arising from a lease by a lessee have not significantly changed from previous guidance. This guidance is effective for interim and annual reporting periods beginning after December 15, 2018, with early adoption permitted, and is required to be adopted using a modified retrospective approach. Sierra Pacific is currently evaluating the impact of adopting this guidance on its Consolidated Financial Statements and disclosures included within Notes to Consolidated Financial Statements.

In May 2014, the FASB issued ASU No. 2014-09, which creates FASB ASC Topic 606, "Revenue from Contracts with Customers" and supersedes ASC Topic 605, "Revenue Recognition." The guidance replaces industry-specific guidance and establishes a single five-step model to identify and recognize revenue. The core principle of the guidance is that an entity should recognize revenue upon transfer of control of promised goods or services to customers in an amount that reflects the consideration to which an entity expects to be entitled in exchange for those goods or services. Additionally, the guidance requires the entity to disclose further quantitative and qualitative information regarding the nature and amount of revenues arising from contracts with customers, as well as other information about the significant judgments and estimates used in recognizing revenues from contracts with customers. In August 2015, the FASB issued ASU No. 2015-14, which defers the effective date of ASU No. 2014-09 one year to interim and annual reporting periods beginning after December 15, 2017. This guidance may be adopted retrospectively or under a modified retrospective method where the cumulative effect is recognized at the date of initial application. Sierra Pacific is currently evaluating the impact of adopting this guidance on its Consolidated Financial Statements and disclosures included within Notes to Consolidated Financial Statements.

125

(3)    Property, Plant and Equipment, Net

Property, plant and equipment, net consists of the following (in millions):

		As of
	Depreciable Life	March 31,			December 31,
		2016			2015
Utility plant:
Electric generation	40 - 125 years	$	1,128		$	1,134
Electric distribution	20 - 70 years	1,393			1,382
Electric transmission	50 - 70 years	748			739
Electric general and intangible plant	5 - 65 years	156			139
Natural gas distribution	40 - 70 years	375			374
Natural gas general and intangible plant	8 - 10 years	15			13
Common general	5 - 65 years	264			265
Utility plant		4,079			4,046
Accumulated depreciation and amortization		(1,382		)	(1,368		)
Utility plant, net		2,697			2,678
Construction work-in-progress		73			88
Property, plant and equipment, net		$	2,770		$	2,766

(4)    Regulatory Matters

Deferred Energy

Nevada statutes permit regulated utilities to adopt deferred energy accounting procedures. The intent of these procedures is to ease the effect on customers of fluctuations in the cost of purchased natural gas, fuel and electricity and are subject to annual prudency review by the Public Utilities Commission of Nevada ("PUCN").

Under deferred energy accounting, to the extent actual fuel and purchased power costs exceed fuel and purchased power costs recoverable through current rates that excess is not recorded as a current expense on the Consolidated Statements of Operations but rather is deferred and recorded as a regulatory asset on the Consolidated Balance Sheets. Conversely, a regulatory liability is recorded to the extent fuel and purchased power costs recoverable through current rates exceed actual fuel and purchased power costs. These excess amounts are reflected in quarterly adjustments to rates and recorded as cost of fuel, energy and capacity in future time periods.

(5) Recent Financing Transactions

In April 2016, Sierra Pacific issued $400 million of its 2.60% General and Refunding Securities, Series U, due May 2026. The net proceeds will be used, together with cash on hand, to pay at maturity the $450 million principal amount of 6.00% General and Refunding Securities, Series M, maturing in May 2016.

In April 2016, Sierra Pacific repurchased at par value $58 million, plus accrued interest, of its Pollution Control Revenue Bonds Series 2006A, due 2031, and $75 million, plus accrued interest, of its Pollution Control Revenue Bonds Series 2006B, due 2036.

(6)    Employee Benefit Plans

Sierra Pacific is a participant in benefit plans sponsored by NV Energy. The NV Energy Retirement Plan includes a qualified pension plan ("Qualified Pension Plan") and a supplemental executive retirement plan and a restoration plan (collectively, "Non‑Qualified Pension Plans") that provide pension benefits for eligible employees. The NV Energy Comprehensive Welfare Benefit and Cafeteria Plan provides certain postretirement health care and life insurance benefits for eligible retirees ("Other Postretirement Plans") on behalf of Sierra Pacific. Amounts attributable to Sierra Pacific were allocated from NV Energy based upon the current, or in the case of retirees, previous, employment location. Offsetting regulatory assets and liabilities have been recorded related to the amounts not yet recognized as a component of net periodic benefit costs that will be included in regulated rates. Net periodic benefit costs not included in regulated rates are included in accumulated other comprehensive loss, net.

126

Amounts payable to NV Energy are included on the Consolidated Balance Sheets and consist of the following (in millions):

	As of
	March 31,			December 31,
	2016			2015
Qualified Pension Plan -
Other long-term liabilities	$	(29	)	$	(29	)
Non-Qualified Pension Plans:
Other current liabilities	(1		)	(1		)
Other long-term liabilities	(9		)	(9		)
Other Postretirement Plans -
Other long-term liabilities	(32		)	(32		)

(7) Fair Value Measurements

The carrying value of Sierra Pacific's cash, certain cash equivalents, receivables, investments held in Rabbi trusts, payables, accrued liabilities and short-term borrowings approximates fair value because of the short-term maturity of these instruments. Sierra Pacific has various financial assets and liabilities, principally related to derivative contracts, that are measured at fair value on the Consolidated Balance Sheets using inputs from the three levels of the fair value hierarchy. A financial asset or liability classification within the hierarchy is determined based on the lowest level input that is significant to the fair value measurement. The three levels are as follows:

• 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.

Sierra Pacific's long-term debt is carried at cost on the Consolidated Balance Sheets. The fair value of Sierra Pacific's long-term debt is a Level 2 fair value measurement and has been estimated based upon quoted market prices, where available, or at the present value of future cash flows discounted at rates consistent with comparable maturities with similar credit risks. The carrying value of Sierra Pacific's variable-rate long-term debt approximates fair value because of the frequent repricing of these instruments at market rates. The following table presents the carrying value and estimated fair value of Sierra Pacific's long-term debt (in millions):

	As of March 31, 2016				As of December 31, 2015
	Carrying		Fair		Carrying		Fair
	Value		Value		Value		Value
Long-term debt	$	1,166	$	1,278	$	1,165	$	1,248

127

(8) Commitments and Contingencies

Environmental Laws and Regulations

Sierra Pacific is subject to federal, state and local laws and regulations regarding air and water quality, renewable portfolio standards, emissions performance standards, climate change, coal combustion byproduct disposal, hazardous and solid waste disposal, protected species and other environmental matters that have the potential to impact Sierra Pacific's current and future operations. Sierra Pacific believes it is in material compliance with all applicable laws and regulations.

Legal Matters

Sierra Pacific is party to a variety of legal actions arising out of the normal course of business. Plaintiffs occasionally seek punitive or exemplary damages. Sierra Pacific does not believe that such normal and routine litigation will have a material impact on its consolidated financial results.

(9)Segment Information

Sierra Pacific has identified two reportable operating segments: regulated electric and regulated natural gas. The regulated electric segment derives most of its revenue from regulated retail sales of electricity to residential, commercial, and industrial customers and from wholesale sales. The regulated natural gas segment derives most of its revenue from regulated retail sales of natural gas to residential, commercial, and industrial customers and also obtains revenue by transporting natural gas owned by others through its distribution system. Pricing for regulated electric and regulated natural gas sales are established separately by the PUCN; therefore, management also reviews each segment separately to make decisions regarding allocation of resources and in evaluating performance.

128

Sierra Pacific believes presenting gross margin allows the reader to assess the impact of Sierra Pacific's regulatory treatment and its overall regulatory environment on a consistent basis and is meaningful. Gross margin is calculated as operating revenue less cost of fuel, energy and capacity and natural gas purchased for resale ("cost of sales"). The following tables provide information on a reportable segment basis (in millions):

	Three-Month Periods
	Ended March 31,
	2016		2015
Operating revenue:
Regulated electric	$	170	$	196
Regulated gas	47		50
Total operating revenue	$	217	$	246
Cost of sales:
Regulated electric	$	70	$	97
Regulated gas	30		35
Total cost of sales	$	100	$	132
Gross margin:
Regulated electric	$	100	$	99
Regulated gas	17		15
Total gross margin	$	117	$	114
Operating and maintenance:
Regulated electric	$	36	$	32
Regulated gas	5		4
Total operating and maintenance	$	41	$	36
Depreciation and amortization:
Regulated electric	$	25	$	24
Regulated gas	4		4
Total depreciation and amortization	$	29	$	28
Operating income:
Regulated electric	$	33	$	37
Regulated gas	8		6
Total operating income	$	41	$	43
Interest expense:
Regulated electric	$	14	$	14
Regulated gas	2		1
Total interest expense	$	16	$	15

129

	As of
	March 31,		December 31,
	2016		2015
Total assets:
Regulated electric	$	3,031	$	3,060
Regulated gas	328		316
Regulated common assets(1)	141		111
Total assets	$	3,500	$	3,487

(1) Consists principally of cash and cash equivalents not included in either the regulated electric or regulated natural gas segments.

130

Item 2.    Management's Discussion and Analysis of Financial Condition and Results of Operations 

General

Sierra Pacific's revenues and operating income are subject to fluctuations during the year due to impacts that seasonal weather, rate changes, and customer usage patterns have on demand for electric energy and resources. Sierra Pacific is a summer peaking utility experiencing its highest retail energy sales in response to the demand for air conditioning. The variations in energy usage due to varying weather, customer growth and other energy usage patterns, including energy efficiency and conservation measures, necessitates a continual balancing of loads and resources and purchases and sales of energy under short- and long-term energy supply contracts. As a result, the prudent management and optimization of available resources has a direct effect on the operating and financial performance of Sierra Pacific. Additionally, the timely recovery of purchased power, fuel costs and other costs and the ability to earn a fair return on investments through rates are essential to the operating and financial performance of Sierra Pacific.

The following is management's discussion and analysis of certain significant factors that have affected the consolidated financial condition and results of operations of Sierra Pacific during the periods included herein. Explanations include management's best estimate of the impact of weather, customer growth and other factors. This discussion should be read in conjunction with Sierra Pacific's historical unaudited Consolidated Financial Statements and Notes to Consolidated Financial Statements in Part I, Item 1 of this Form 10-Q. Sierra Pacific's actual results in the future could differ significantly from the historical results.

131

Results of Operations for the First Quarterof 2016 and 2015

Overview

Net income for the first quarter of 2016 was $17 million, a decrease of $2 million, or 11%, compared to 2015 primarily due to higher planned maintenance and other generating costs, partially offset by higher natural gas margins from increased customer usage due to the impacts of weather.

Operating revenue, cost of fuel, energy and capacity and natural gas purchased for resale are key drivers of Sierra Pacific's results of operations as they encompass retail and wholesale electricity and natural gas revenue and the direct costs associated with providing electricity and natural gas to customers. Sierra Pacific believes that a discussion of gross margin, representing operating revenue less cost of fuel, energy and capacity and natural gas purchased for resale, is therefore meaningful. A comparison of Sierra Pacific's key operating results is as follows:

Electric Gross Margin

	First Quarter
	2016		2015		Change
Gross margin (in millions):
Operating electric revenue	$	170	$	196	$	(26	)	(13	)	%
Cost of fuel, energy and capacity	70		97		(27		)	(28	)
Gross margin	$	100	$	99	$	1		1
GWh sold:
Residential	609		591		18			3		%
Commercial	649		666		(17		)	(3	)
Industrial	738		717		21			3
Other	4		4		—			—
Total retail	2,000		1,978		22			1
Wholesale	188		182		6			3
Total GWh sold	2,188		2,160		28			1
Average number of retail customers (in thousands):
Residential	290		287		3			1		%
Commercial	47		46		1			2
Total	337		333		4			1
Average retail revenue per MWh	$	78.33	$	91.86	$	(13.53	)	(15	)	%
Heating degree days	1,960		1,668		292			18		%
Sources of energy (GWh)(1):
Coal	214		340		(126		)	(37	)	%
Natural gas	989		978		11			1
Total energy generated	1,203		1,318		(115		)	(9	)
Energy purchased	1,144		927		217			23
Total	2,347		2,245		102			5

(1)    GWh amounts are net of energy used by the related generating facilities.

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Natural Gas Gross Margin

	First Quarter
	2016		2015		Change
Gross margin (in millions):
Operating natural gas revenue	$	47	$	50	$	(3	)	(6	)	%
Natural gas purchased for resale	30		35		(5		)	(14	)
Gross margin	$	17	$	15	$	2		13
Dth sold:
Residential	3,863		3,215		648			20		%
Commercial	2,032		1,615		417			26
Industrial	573		525		48			9
Total retail	6,468		5,355		1,113			21
Average number of retail customers (in thousands)	161		158		3			2		%
Average revenue per retail Dth sold	$	7.04	$	9.15	$	(2.11	)	(23	)	%
Average cost of natural gas per retail Dth sold	$	4.50	$	6.48	$	(1.98	)	(31	)	%
Heating degree days	1,960		1,668		292			18		%

Electric gross margin increased $1 million, or 1%, for the first quarter of 2016 compared to 2015 due to higher energy efficiency program rate revenue, which is offset in operating and maintenance expense.

Natural gas gross margin increased $2 million, or 13%, for the first quarter of 2016 compared to 2015 due to higher customer usage, primarily from the impacts of weather.

Operating and maintenance increased $5 million, or 14%, for the first quarter of 2016 compared to 2015 due to planned maintenance and other generating costs and higher energy efficiency program costs, which are fully recovered in operating revenue.

Income tax expense decreased $1 million, or 9%, for the first quarter of 2016 compared to 2015. The effective tax rate was 37% for 2016 and 2015.

Liquidity and Capital Resources

As of March 31, 2016, Sierra Pacific's total net liquidity was $385 million consisting of $135 million in cash and cash equivalents and $250 million of revolving credit facility availability.

Operating Activities

Net cash flows from operating activities for the three-month periods ended March 31, 2016 and 2015 were $78 million and $76 million, respectively. The change was due to lower payments for fuel costs, partially offset by decreased collections from customers due to lower retail rates as a result of deferred energy adjustment mechanisms.

In December 2015, the Protecting Americans from Tax Hikes Act of 2015 ("PATH") was signed into law, extending bonus depreciation for qualifying property acquired and placed in-service before January 1, 2020 (bonus depreciation rates will be 50% for 2015-2017, 40% in 2018, and 30% in 2019), with an additional year for certain longer lived assets. Investment tax credits were extended and phased-down for solar projects that are under construction before the end of 2021 (investment tax credit rates are 30% through 2019, 26% in 2020 and 22% in 2021; they revert to the statutory rate of 10% thereafter). As a result of PATH, Sierra Pacific's cash flows from operations are expected to benefit in 2016 and beyond due to bonus depreciation on qualifying assets placed in-service and investment tax credits (once the net operating loss is fully utilized) earned on qualifying projects.

Investing Activities

Net cash flows from investing activities for the three-month periods ended March 31, 2016 and 2015 were $(48) million and $(45) million, respectively. The change was primarily due to cash received from the sale of securities in 2015.

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Financing Activities

Net cash flows from financing activities for the three-month periods ended March 31, 2016 and 2015 were $(1) million and $‑ million, respectively. The change was primarily due to repayments of financial and capital lease obligations.

In April 2016, Sierra Pacific issued $400 million of its 2.60% General and Refunding Securities, Series U, due May 2026. The net proceeds will be used, together with cash on hand, to pay at maturity the $450 million principal amount of 6.00% General and Refunding Securities, Series M, maturing in May 2016.

In April 2016, Sierra Pacific repurchased at par value $58 million, plus accrued interest, of its Pollution Control Revenue Bonds Series 2006A, due 2031, and $75 million, plus accrued interest, of its Pollution Control Revenue Bonds Series 2006B, due 2036.

Ability to Issue Debt

Sierra Pacific's ability to issue debt is primarily impacted by its financing authority from the PUCN. As of March 31, 2016, Sierra Pacific has financing authority from the PUCN consisting of the ability to: (1) issue additional long-term debt securities of up to $350 million; (2) refinance up to $798 million of long-term debt securities; and (3) maintain a revolving credit facility of up to $600 million. Sierra Pacific's revolving credit facility contains a financial maintenance covenant which Sierra Pacific was in compliance with as of March 31, 2016. In addition, certain financing agreements contain covenants which are currently suspended as Sierra Pacific's senior secured debt is rated investment grade. However, if Sierra Pacific's senior secured debt ratings fall below investment grade by either Moody's Investors Service or Standard & Poor's, Sierra Pacific would be subject to limitations under these covenants.

Future Uses of Cash

Sierra Pacific has available a variety of sources of liquidity and capital resources, both internal and external, including net cash flows from operating activities, public and private debt offerings, the use of its secured revolving credit facility, capital contributions and other sources. These sources are expected to provide funds required for current operations, capital expenditures, debt retirements and other capital requirements. The availability and terms under which Sierra Pacific has access to external financing depends on a variety of factors, including Sierra Pacific's credit ratings, investors' judgment of risk and conditions in the overall capital markets, including the condition of the utility industry.

Capital Expenditures

Sierra Pacific has significant future capital requirements. Capital expenditure needs are reviewed regularly by management and may change significantly as a result of these reviews, which may consider, among other factors, changes in environmental and other rules and regulations; impacts to customers' rates; outcomes of regulatory proceedings; changes in income tax laws; general business conditions; load projections; system reliability standards; the cost and efficiency of construction labor, equipment and materials; commodity prices; and the cost and availability of capital. Expenditures for certain assets may ultimately include acquisitions of existing assets.

Sierra Pacific's historical and forecast capital expenditures, each of which exclude amounts for non-cash equity AFUDC and other non-cash items are as follows (in millions):

	Three-Month Periods				Annual
	Ended March 31,				Forecast
	2015		2016		2016
Distribution	$	23	$	16	$	104
Transmission system investment	3		3		36
Other	21		29		65
Total	$	47	$	48	$	205

Contractual Obligations

As of March 31, 2016, there have been no material changes outside the normal course of business in contractual obligations from the information provided in Item 7 of Sierra Pacific's Annual Report on Form 10-K for the year ended December 31, 2015.

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Regulatory Matters

Sierra Pacific is subject to comprehensive regulation. Refer to "Regulatory Matters" in Berkshire Hathaway Energy's Part I, Item 2 of this Form 10-Q for discussion regarding Sierra Pacific's current regulatory matters.

Environmental Laws and Regulations

Sierra Pacific is subject to federal, state and local laws and regulations regarding air and water quality, RPS, emissions performance standards, climate change, coal combustion byproduct disposal, hazardous and solid waste disposal, protected species and other environmental matters that have the potential to impact Sierra Pacific's current and future operations. In addition to imposing continuing compliance obligations and capital expenditure requirements, these laws and regulations provide regulators with the authority to levy substantial penalties for noncompliance including fines, injunctive relief and other sanctions. These laws and regulations are administered by the EPA and various state and local agencies. All such laws and regulations are subject to a range of interpretation, which may ultimately be resolved by the courts. Environmental laws and regulations continue to evolve, and Sierra Pacific is unable to predict the impact of the changing laws and regulations on its operations and consolidated financial results. Sierra Pacific believes it is in material compliance with all applicable laws and regulations. Refer to "Liquidity and Capital Resources" for discussion of Sierra Pacific's forecasted environmental-related capital expenditures.

Refer to "Environmental Laws and Regulations" in Berkshire Hathaway Energy's Part I, Item 2 of this Form 10-Q for additional information regarding environmental laws and regulations.

New Accounting Pronouncements

For a discussion of new accounting pronouncements affecting Sierra Pacific, refer to Note 2 of Notes to Consolidated Financial Statements in Sierra Pacific's Part I, Item 1 of this Form 10-Q.

Critical Accounting Estimates

Certain accounting measurements require management to make estimates and judgments concerning transactions that will be settled several years in the future. Amounts recognized on the Consolidated Financial Statements based on such estimates involve numerous assumptions subject to varying and potentially significant degrees of judgment and uncertainty and will likely change in the future as additional information becomes available. Estimates are used for, but not limited to, the accounting for the effects of certain types of regulation, derivatives, impairment of long-lived assets, income taxes and revenue recognition - unbilled revenue. For additional discussion of Sierra Pacific's critical accounting estimates, see Item 7 of Sierra Pacific's Annual Report on Form 10‑K for the year ended December 31, 2015. There have been no significant changes in Sierra Pacific's assumptions regarding critical accounting estimates since December 31, 2015.

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Item 3. Quantitative and Qualitative Disclosures About Market Risk

For quantitative and qualitative disclosures about market risk affecting the Registrants, see Item 7A of each Registrant's Annual Report on Form 10-K for the year ended December 31, 2015. Each Registrant's exposure to market risk and its management of such risk has not changed materially since December 31, 2015. Refer to Note 8 of the Notes to Consolidated Financial Statements of Berkshire Hathaway Energy in Part I, Item 1 of this Form 10-Q, Note 5 of the Notes to Consolidated Financial Statements of PacifiCorp in Part I, Item 1 of this Form 10-Q, Note 6 of the Notes to Financial Statements of MidAmerican Energy in Part I, Item 1 of this Form 10-Q and Note 6 of the Notes to Consolidated Financial Statements of Nevada Power in Part I, Item 1 of this Form 10-Q for disclosure of the respective Registrant's derivative positions as of March 31, 2016.

Item 4. Controls and Procedures

At the end of the period covered by this Quarterly Report on Form 10-Q, each of Berkshire Hathaway Energy Company, PacifiCorp, MidAmerican Funding, LLC, MidAmerican Energy Company, Nevada Power Company and Sierra Pacific Power Company carried out separate evaluations, under the supervision and with the participation of each such entity's management, including its Chief Executive Officer (principal executive officer) and its Chief Financial Officer (principal financial officer), or persons performing similar functions, of the effectiveness of the design and operation of its disclosure controls and procedures (as defined in Rule 13a-15(e) promulgated under the Securities and Exchange Act of 1934, as amended). Based upon these evaluations, management of each such entity, including its Chief Executive Officer (principal executive officer) and its Chief Financial Officer (principal financial officer), or persons performing similar functions, in each case, concluded that the disclosure controls and procedures for such entity were effective to ensure that information required to be disclosed by such entity in the reports that it files or submits under the Securities and Exchange Act of 1934, as amended, is recorded, processed, summarized and reported within the time periods specified in the United States Securities and Exchange Commission's rules and forms, and is accumulated and communicated to its management, including its Chief Executive Officer (principal executive officer) and its Chief Financial Officer (principal financial officer), or persons performing similar functions, in each case, as appropriate to allow timely decisions regarding required disclosure by it. Each such entity hereby states that there has been no change in its internal control over financial reporting during the quarter ended March 31, 2016 that has materially affected, or is reasonably likely to materially affect, its internal control over financial reporting.

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PART II

Item 1. Legal Proceedings

For a description of certain legal proceedings affecting PacifiCorp, refer to Note 7 of the Notes to Consolidated Financial Statements of PacifiCorp in Part I, Item 1 of this Form 10-Q.

Item 1A. Risk Factors

There has been no material change to each Registrant's risk factors from those disclosed in Item 1A of each Registrant's Annual Report on Form 10-K for the year ended December 31, 2015.

Item 2. Unregistered Sales of Equity Securities and Use of Proceeds

Not applicable.

Item 3. Defaults Upon Senior Securities

Not applicable.

Item 4. Mine Safety Disclosures

Information regarding Berkshire Hathaway Energy's and PacifiCorp's mine safety violations and other legal matters disclosed in accordance with Section 1503(a) of the Dodd-Frank Wall Street Reform and Consumer Protection Act is included in Exhibit 95 to this Form 10-Q.

Item 5. Other Information

None of the Registrants engaged in any activities as defined under Section 13(r) of the Securities Exchange Act of 1934, as amended, during the period covered by this Quarterly Report on Form 10-Q.

However, Section 13(r) of the Securities Exchange Act of 1934 requires an issuer to disclose in its annual or quarterly reports, as applicable, whether it or any of its affiliates knowingly engaged in certain activities, transactions or dealings relating to Iran. Because of the broad definition of "affiliate" in Rule 12b-2 of the Securities Exchange Act of 1934, disclosure is required by the Registrants.

Berkshire Hathaway Inc., the ultimate parent company of each Registrant, has provided each Registrant the disclosure set forth below describing the Iran Threat Reduction and Syria Human Rights Act of 2012 activities of one of Berkshire Hathaway Inc.'s foreign subsidiaries. All references in this quoted disclosure to "we" and "our" are to Berkshire Hathaway Inc.

Disclosures Under Iran Threat Reduction and Syria Human Rights Act of 2012

We are making the following disclosures under Section 13(r) of the Exchange Act because our management recently became aware that one of our foreign subsidiaries made sales through a third-party distributor to customers in Iran that include or may include parties (the "Iran Parties") that meet the definition of the "Government of Iran" under Section 560.304 of 31 C.F.R. Part 560. Based upon currently known information, total revenues to our subsidiary from sales to the Iran Parties, which took place from June 2013 through November 2015, were approximately $45,000, and the total net income attributable to those sales was approximately $2,500.

Our subsidiary has stopped all shipments to the Iran Parties, and the subsidiary does not intend to continue sales to, or engage in other dealings with, the Iran Parties. On May 6, 2016, we submitted initial notifications of voluntary self-disclosures to the U.S. Department of the Treasury, Office of Foreign Assets Control ("OFAC"), and the U.S. Department of Commerce, Bureau of Industry and Security ("BIS"). We will submit further information to OFAC and BIS after completing an internal investigation, which we are conducting with the assistance of outside counsel, and we intend to cooperate fully with both agencies.

Item 6. Exhibits

The exhibits listed on the accompanying Exhibit Index are filed as part of this Quarterly Report.

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SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, each registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.

	BERKSHIRE HATHAWAY ENERGY COMPANY
Date: May 6, 2016	/s/ Patrick J. Goodman
	Patrick J. Goodman
	Executive Vice President and Chief Financial Officer
	(principal financial and accounting officer)
	PACIFICORP
Date: May 6, 2016	/s/ Nikki L. Kobliha
	Nikki L. Kobliha
	Vice President and Chief Financial Officer
	(principal financial and accounting officer)
	MIDAMERICAN FUNDING, LLC
	MIDAMERICAN ENERGY COMPANY
Date: May 6, 2016	/s/ Thomas B. Specketer
	Thomas B. Specketer
	Vice President and Controller
	of MidAmerican Funding, LLC
	and Vice President, Chief Financial Officer and Director
	of MidAmerican Energy Company
	(principal financial and accounting officer)
	NEVADA POWER COMPANY
Date: May 6, 2016	/s/ E. Kevin Bethel
	E. Kevin Bethel
	Senior Vice President, Chief Financial Officer and Director
	(principal financial and accounting officer)
	SIERRA PACIFIC POWER COMPANY
Date: May 6, 2016	/s/ E. Kevin Bethel
	E. Kevin Bethel
	Senior Vice President, Chief Financial Officer and Director
	(principal financial and accounting officer)

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EXHIBIT INDEX

Exhibit No. Description

BERKSHIRE HATHAWAY ENERGY

15.1 Awareness Letter of Independent Registered Public Accounting Firm.

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.

PACIFICORP

15.2 Awareness Letter of Independent Registered Public Accounting Firm.

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.

BERKSHIRE HATHAWAY ENERGY AND PACIFICORP

95 Mine Safety Disclosures Required by the Dodd-Frank Wall Street Reform and Consumer Protection Act.

MIDAMERICAN ENERGY

15.3 Awareness Letter of Independent Registered Public Accounting Firm.

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.

MIDAMERICAN FUNDING

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.

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Exhibit No.Description

NEVADA POWER

15.4 Awareness Letter of Independent Registered Public Accounting Firm.

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.

SIERRA PACIFIC

15.5 Awareness Letter of Independent Registered Public Accounting Firm.

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.

BERKSHIRE HATHAWAY ENERGY AND SIERRA PACIFIC

4.1 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).

ALL REGISTRANTS

101 The following financial information from each respective Registrant's Quarterly Report on Form 10-Q for the quarter ended March 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.

140