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AVA Avista

Filed: 4 Aug 20, 9:41pm

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

 

 

Form 10-Q

 

(Mark One)

 

QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

 

 

 

FOR THE QUARTERLY PERIOD ENDED June 30, 2020 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 1-3701

 

 

AVISTA CORPORATION

(Exact name of Registrant as specified in its charter)

 

Washington

 

91-0462470

(State or other jurisdiction of

incorporation or organization)

 

(I.R.S. Employer
Identification No.)

 

1411 East Mission Avenue, Spokane, Washington 99202-2600

(Address of principal executive offices, including zip code)

Registrant’s telephone number, including area code: 509-489-0500

None

(Former name, former address and former fiscal year, if changed since last report)

Securities registered pursuant to Section 12(b) of the Act:

 

Title of Each Class

 

Trading Symbol(s)

 

Name of Each Exchange on Which Registered

Common Stock

 

AVA

 

New York Stock Exchange

 

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:    Yes      No  

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted 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 registrant was required to submit and post such files).    Yes      No  

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

 

Large accelerated filer

Accelerated filer

Non-accelerated filer

Smaller reporting company

Emerging growth company

 

 

 

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act   

Indicate by check mark whether the Registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act):    Yes      No  

As of July 31, 2020, 67,914,755 shares of Registrant’s Common Stock, no par value (the only class of common stock), were outstanding.

 

 


Table of Contents

 

AVISTA CORPORATION

 

AVISTA CORPORATION

INDEX

Item No.

 

 

Page No.

 

 

 

 

 

Acronyms and Terms

 

iii

 

Forward-Looking Statements

 

1

 

Available Information

 

4

Part I. Financial Information

 

 

Item 1.

Condensed Consolidated Financial Statements

 

5

 

Condensed Consolidated Statements of Income -
Three and Six Months Ended June 30, 2020 and 2019

 

5

 

Condensed Consolidated Statements of Comprehensive Income -
Three and Six Months Ended June 30, 2020 and 2019

 

6

 

Condensed Consolidated Balance Sheets -
June 30, 2020 and December 31, 2019

 

7

 

Condensed Consolidated Statements of Cash Flows -
Six Months Ended June 30, 2020 and 2019

 

8

 

Condensed Consolidated Statements of Equity -
Three and Six Months Ended June 30, 2020 and 2019

 

10

 

Notes to Condensed Consolidated Financial Statements

 

11

 

Note 1. Summary of Significant Accounting Policies

 

11

 

Note 2. New Accounting Standards

 

12

 

Note 3. Balance Sheet Components

 

13

 

Note 4. Revenue

 

15

 

Note 5. Derivatives and Risk Management

 

20

 

Note 6. Pension Plans and Other Postretirement Benefit Plans

 

24

 

Note 7. Income Taxes

 

25

 

Note 8. Committed Lines of Credit

 

26

 

Note 9. Credit Agreement

 

26

 

Note 10. Long-Term Debt to Affiliated Trusts

 

27

 

Note 11. Fair Value

 

27

 

Note 12. Common Stock

 

32

 

Note 13. Accumulated Other Comprehensive Loss

 

32

 

Note 14. Earnings per Common Share Attributable to Avista Corporation Shareholders

 

33

 

Note 15. Commitments and Contingencies

 

33

 

Note 16. Information by Business Segments

 

34

 

Note 17. Termination of Proposed Acquisition by Hydro One

 

36

 

Note 18. Sale of METALfx

 

36

 

Report of Independent Registered Public Accounting Firm

 

37

 

 

 

 

Item 2.

Management’s Discussion and Analysis of Financial Condition and Results of Operations

 

38

 

Business Segments

 

38

 

Executive Level Summary

 

38

 

Regulatory Matters

 

40

 

Results of Operations - Overall

 

44

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Table of Contents

 

 

Non-GAAP Financial Measures

 

47

 

Results of Operations - Avista Utilities

 

48

 

Results of Operations - Alaska Electric Light and Power Company

 

62

 

Results of Operations - Other Businesses

 

63

 

Critical Accounting Policies and Estimates

 

63

 

Liquidity and Capital Resources

 

63

 

Overall Liquidity

 

63

 

Review of Cash Flow Statement

 

63

 

Capital Resources

 

64

 

Capital Expenditures

 

65

 

Off-Balance Sheet Arrangements

 

66

 

Pension Plan

 

66

 

Contractual Obligations

 

66

 

Environmental Issues and Other Contingencies

 

66

 

Enterprise Risk Management

 

69

 

 

 

 

Item 3.

Quantitative and Qualitative Disclosures about Market Risk

 

70

 

 

 

 

Item 4.

Controls and Procedures

 

70

 

 

 

 

Part II. Other Information

 

 

Item 1.

Legal Proceedings

 

72

 

 

 

 

Item 1A.

Risk Factors

 

72

 

 

 

 

Item 6.

Exhibits

 

74

 

 

 

 

 

Signature

 

75

 

 

 

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AVISTA CORPORATION

 

ACRONYMS AND TERMS

(The following acronyms and terms are found in multiple locations within the document)

 

Acronym/Term

Meaning

aMW

-

Average Megawatt - a measure of the average rate at which a particular generating source produces energy over a period of time

AEL&P

-

Alaska Electric Light and Power Company, the primary operating subsidiary of AERC, which provides electric services in Juneau, Alaska

AERC

-

Alaska Energy and Resources Company, the Company's wholly-owned subsidiary based in Juneau, Alaska

AFUDC

-

Allowance for Funds Used During Construction; represents the cost of both the debt and equity funds used to finance utility plant additions during the construction period

ASC

-

Accounting Standards Codification

ASU

-

Accounting Standards Update

Avista Capital

-

Parent company to the Company’s non-utility businesses, with the exception of AJT Mining Properties, Inc., which is a subsidiary of AERC.

Avista Corp.

-

Avista Corporation, the Company

Avista Utilities

-

Operating division of Avista Corp. (not a subsidiary) comprising the regulated utility operations in the Pacific Northwest

Capacity

-

The rate at which a particular generating source is capable of producing energy, measured in KW or MW

Cabinet Gorge

-

The Cabinet Gorge Hydroelectric Generating Project, located on the Clark Fork River in Idaho

Colstrip

-

The coal-fired Colstrip Generating Plant in southeastern Montana

Cooling degree days

-

The measure of the warmness of weather experienced, based on the extent to which the average of high and low temperatures for a day exceeds 65 degrees Fahrenheit (annual degree days above historic indicate warmer than average temperatures)

COVID-19

-

Coronavirus disease 2019, a respiratory illness that was declared a pandemic in March 2020

Deadband or ERM
deadband

-

The first $4.0 million in annual power supply costs above or below the amount included in base retail rates in Washington under the ERM in the state of Washington

EIM

-

Energy Imbalance Market

Energy

-

The amount of electricity produced or consumed over a period of time, measured in KWh or MWh. Also, refers to natural gas consumed and is measured in dekatherms

EPA

-

Environmental Protection Agency

ERM

-

The Energy Recovery Mechanism, a mechanism for accounting and rate recovery of certain power supply costs accepted by the utility commission in the state of Washington

FASB

-

Financial Accounting Standards Board

FCA

-

Fixed Cost Adjustment, the electric and natural gas decoupling mechanism in Idaho

FERC

-

Federal Energy Regulatory Commission

GAAP

-

Generally Accepted Accounting Principles

Heating degree days

-

The measure of the coldness of weather experienced, based on the extent to which the average of high and low temperatures for a day falls below 65 degrees Fahrenheit (annual degree days below historic indicate warmer than average temperatures).

Hydro One

-

Hydro One Limited, based in Toronto, Ontario, Canada

IPUC

-

Idaho Public Utilities Commission

Juneau

-

The City and Borough of Juneau, Alaska

KW, KWh

-

Kilowatt (1000 watts): a measure of generating power or capability.  Kilowatt-hour (1000 watt hours): a measure of energy produced over a period of time

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MPSC

-

Public Service Commission of the State of Montana

MW, MWh

-

Megawatt: 1000 KW.  Megawatt-hour: 1000 KWh

Noxon Rapids

-

The Noxon Rapids Hydroelectric Generating Project, located on the Clark Fork River in Montana

OPUC

-

The Public Utility Commission of Oregon

PCA

-

The Power Cost Adjustment mechanism, a procedure for accounting and rate recovery of certain power supply costs accepted by the utility commission in the state of Idaho

PGA

-

Purchased Gas Adjustment

PPA

-

Power Purchase Agreement

RCA

-

The Regulatory Commission of Alaska

REC

-

Renewable energy credit

ROE

-

Return on equity

ROR

-

Rate of return on rate base

ROU

-

Right-of-use lease asset

SEC

-

U.S. Securities and Exchange Commission

TCJA

-

The "Tax Cuts and Jobs Act," signed into law on December 22, 2017

Therm

-

Unit of measurement for natural gas; a therm is equal to approximately one hundred cubic feet (volume) or 100,000 BTUs (energy)

Watt

-

Unit of measurement of electric power or capability; a watt is equal to the rate of work represented by a current of one ampere under a pressure of one volt

WUTC

-

Washington Utilities and Transportation Commission

 

 

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AVISTA CORPORATION

 

Forward-Looking Statements

From time to time, we make forward-looking statements such as statements regarding projected or future:

 

financial performance;

 

cash flows;

 

capital expenditures;

 

dividends;

 

capital structure;

 

other financial items;

 

strategic goals and objectives;

 

business environment; and

 

plans for operations.

These statements are based upon underlying assumptions (many of which are based, in turn, upon further assumptions). Such statements are made both in our reports filed under the Securities Exchange Act of 1934, as amended (including this Quarterly Report on Form 10-Q), and elsewhere. Forward-looking statements are all statements except those of historical fact including, without limitation, those that are identified by the use of words that include “will,” “may,” “could,” “should,” “intends,” “plans,” “seeks,” “anticipates,” “estimates,” “expects,” “forecasts,” “projects,” “predicts,” and similar expressions.

Forward-looking statements (including those made in this Quarterly Report on Form 10-Q) are subject to a variety of risks, uncertainties and other factors. Most of these factors are beyond our control and may have a significant effect on our operations, results of operations, financial condition or cash flows, which could cause actual results to differ materially from those anticipated in our statements. Such risks, uncertainties and other factors include, among others:

Utility Regulatory Risk

state and federal regulatory decisions or related judicial decisions that affect our ability to recover costs and earn a reasonable return including, but not limited to, disallowance or delay in the recovery of capital investments, operating costs, commodity costs, interest rate swap derivatives, the ordering of refunds to customers and discretion over allowed return on investment;

the loss of regulatory accounting treatment, which could require the write-off of regulatory assets and the loss of regulatory deferral and recovery mechanisms;

Operational Risk

pandemics (including the current COVID-19 pandemic), which could disrupt our business, as well as the global, national and local economy, resulting in a decline in customer demand, deterioration in the creditworthiness of our customers, increases in operating and capital costs, workforce shortages, delays in capital projects, disruption in supply chains, and disruption, weakness and volatility in capital markets. In addition, any of these factors could negatively impact our liquidity and limit our access to capital, among other implications;

wildfires ignited, or allegedly ignited, by Avista Corp. equipment or facilities could cause significant loss of life and property, thereby causing serious operational and financial harm to Avista Corp. and our customers;

severe weather or natural disasters, including, but not limited to, avalanches, wind storms, wildfires, earthquakes, snow and ice storms, that can disrupt energy generation, transmission and distribution, as well as the availability and costs of fuel, materials, equipment, supplies and support services;

explosions, fires, accidents, mechanical breakdowns or other incidents that could impair assets and may disrupt operations of any of our generation facilities, transmission, and electric and natural gas distribution systems or other operations and may require us to purchase replacement power or incur costs to repair our facilities;

explosions, fires, accidents or other incidents arising from or allegedly arising from our operations that could cause injuries to the public or property damage;

blackouts or disruptions of interconnected transmission systems (the regional power grid);

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terrorist attacks, cyberattacks or other malicious acts that could disrupt or cause damage to our utility assets or to the national or regional economy in general, including any effects of terrorism, cyberattacks, ransomware, or vandalism that damage or disrupt information technology systems;

work-force issues, including changes in collective bargaining unit agreements, strikes, work stoppages, the loss of key executives, availability of workers in a variety of skill areas, and our ability to recruit and retain employees;

increasing costs of insurance, more restrictive coverage terms and our ability to obtain insurance;

delays or changes in construction costs, and/or our ability to obtain required permits and materials for present or prospective facilities;

increasing health care costs and cost of health insurance provided to our employees and retirees;

third party construction of buildings, billboard signs, towers or other structures within our rights of way, or placement of fuel containers within close proximity to our transformers or other equipment, including overbuild atop natural gas distribution lines;

the loss of key suppliers for materials or services or other disruptions to the supply chain;

adverse impacts to our Alaska electric utility that could result from an extended outage of its hydroelectric generating resources or their inability to deliver energy, due to their lack of interconnectivity to any other electrical grids and the availability or cost of replacement power (diesel);

changing river regulation or operations at hydroelectric facilities not owned by us, which could impact our hydroelectric facilities downstream;

change in the use, availability or abundancy of water resources and/or rights needed for operation of our hydroelectric facilities;

Cyber and Technology Risk

cyberattacks on the operating systems that are used in the operation of our electric generation, transmission and distribution facilities and our natural gas distribution facilities, and cyberattacks on such systems of other energy companies with which we are interconnected, which could damage or destroy facilities or systems or disrupt operations for extended periods of time and result in the incurrence of liabilities and costs;

cyberattacks on the administrative systems that are used in the administration of our business, including customer billing and customer service, accounting, communications, compliance and other administrative functions, and cyberattacks on such systems of our vendors and other companies with which we do business, which could result in the disruption of business operations, the release of private information and the incurrence of liabilities and costs;

changes in costs that impede our ability to effectively implement new information technology systems or to operate and maintain current production technology;

changes in technologies, possibly making some of the current technology we utilize obsolete or introducing new cyber security risks;

insufficient technology skills, which could lead to the inability to develop, modify or maintain our information systems;

Strategic Risk

growth or decline of our customer base due to new uses for our services or decline in existing services, including, but not limited to, the effect of the trend toward distributed generation at customer sites;

the potential effects of negative publicity regarding our business practices, whether true or not, which could hurt our reputation and result in litigation or a decline in our common stock price;

changes in our strategic business plans, which could be affected by any or all of the foregoing, including the entry into new businesses and/or the exit from existing businesses and the extent of our business development efforts where potential future business is uncertain;

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wholesale and retail competition including alternative energy sources, growth in customer-owned power resource technologies that displace utility-supplied energy or that may be sold back to the utility, and alternative energy suppliers and delivery arrangements;

entering into or growth of non-regulated activities may increase earnings volatility;

the risk of municipalization or other forms of service territory reduction;

External Mandates Risk

changes in environmental laws, regulations, decisions and policies, including present and potential environmental remediation costs and our compliance with these matters;

the potential effects of initiatives, legislation or administrative rulemaking at the federal, state or local levels, including possible effects on our generating resources, prohibitions or restrictions on new or existing services, or restrictions on greenhouse gas emissions to mitigate concerns over global climate changes;

political pressures or regulatory practices that could constrain or place additional cost burdens on our distribution systems through accelerated adoption of distributed generation or electric-powered transportation or on our energy supply sources, such as campaigns to halt fossil fuel fired power generation and opposition to other thermal generation, wind turbines or hydroelectric facilities;

failure to identify changes in legislation, taxation and regulatory issues that could be detrimental or beneficial to our overall business;

policy and/or legislative changes in various regulated areas, including, but not limited to, environmental regulation, healthcare regulations and import/export regulations;

Financial Risk

weather conditions, which affect both energy demand and electric generating capability, including the impact of precipitation and temperature on hydroelectric resources, the impact of wind patterns on wind-generated power, weather-sensitive customer demand, and similar impacts on supply and demand in the wholesale energy markets;

our ability to obtain financing through the issuance of debt and/or equity securities, which could be affected by various factors including our credit ratings, interest rates, other capital market conditions and global economic conditions;

changes in interest rates that affect borrowing costs, our ability to effectively hedge interest rates for anticipated debt issuances, variable interest rate borrowing and the extent to which we recover interest costs through retail rates collected from customers;

changes in actuarial assumptions, interest rates and the actual return on plan assets for our pension and other postretirement benefit plans, which could affect future funding obligations, pension and other postretirement benefit expense and the related liabilities;

the outcome of legal proceedings and other contingencies;

economic conditions in our service areas, including the economy's effects on customer demand for utility services;

economic conditions nationally may affect the valuation of our unregulated portfolio companies;

declining energy demand related to customer energy efficiency, conservation measures and/or increased distributed generation;

changes in the long-term climate and weather could materially affect, among other things, customer demand, the volume and timing of streamflows required for hydroelectric generation, costs of generation, transmission and distribution. Increased or new risks may arise from severe weather or natural disasters, including wildfires;

industry and geographic concentrations which could increase our exposure to credit risks due to counterparties, suppliers and customers being similarly affected by changing conditions;

deterioration in the creditworthiness of our customers;

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AVISTA CORPORATION

 

Energy Commodity Risk

volatility and illiquidity in wholesale energy markets, including exchanges, the availability of willing buyers and sellers, changes in wholesale energy prices that could affect operating income, cash requirements to purchase electricity and natural gas, value received for wholesale sales, collateral required of us by individual counterparties and/or exchanges in wholesale energy transactions and credit risk to us from such transactions, and the market value of derivative assets and liabilities;

default or nonperformance on the part of any parties from whom we purchase and/or sell capacity or energy;

potential environmental regulations or lawsuits affecting our ability to utilize or resulting in the obsolescence of our power supply resources;

explosions, fires, accidents, pipeline ruptures or other incidents that could limit energy supply to our facilities or our surrounding territory, which could result in a shortage of commodities in the market that could increase the cost of replacement commodities from other sources;

Compliance Risk

changes in laws, regulations, decisions and policies at the federal, state or local levels, which could materially impact both our electric and gas operations and costs of operations; and

the ability to comply with the terms of the licenses and permits for our hydroelectric or thermal generating facilities at cost-effective levels.

Our expectations, beliefs and projections are expressed in good faith. We believe they are reasonable based on, without limitation, an examination of historical operating trends, our records and other information available from third parties. There can be no assurance that our expectations, beliefs or projections will be achieved or accomplished. Furthermore, any forward-looking statement speaks only as of the date on which such statement is made. We undertake no obligation to update any forward-looking statement or statements to reflect events or circumstances that occur after the date on which such statement is made or to reflect the occurrence of unanticipated events. New risks, uncertainties and other factors emerge from time to time, and it is not possible for us to predict all such factors, nor can we assess the effect of each such factor on our business or the extent that any such factor or combination of factors may cause actual results to differ materially from those contained in any forward-looking statement.

Available Information

We file annual, quarterly and current reports and proxy statements with the SEC. The SEC maintains a website that contains these documents at www.sec.gov. We make annual, quarterly and current reports and proxy statements available on our website, www.avistacorp.com, as soon as practicable after electronically filing these documents with the SEC. Except for SEC filings or portions thereof that are specifically referred to in this report, information contained on these websites is not part of this report.

 

 

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PART I. Financial Information

Item 1. Condensed Consolidated Financial Statements

CONDENSED CONSOLIDATED STATEMENTS OF INCOME

Avista Corporation

 

For the Three and Six Months Ended June 30

Dollars in thousands, except per share amounts

(Unaudited)

 

 

 

Three months ended June 30,

 

 

Six months ended June 30,

 

 

 

2020

 

 

2019

 

 

2020

 

 

2019

 

Operating Revenues:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Utility revenues:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Utility revenues, exclusive of alternative revenue

   programs

 

$

273,975

 

 

$

288,826

 

 

$

667,795

 

 

$

682,067

 

Alternative revenue programs

 

 

4,362

 

 

 

9,725

 

 

 

(51

)

 

 

5,067

 

Total utility revenues

 

 

278,337

 

 

 

298,551

 

 

 

667,744

 

 

 

687,134

 

Non-utility revenues

 

 

255

 

 

 

2,261

 

 

 

1,078

 

 

 

10,159

 

Total operating revenues

 

 

278,592

 

 

 

300,812

 

 

 

668,822

 

 

 

697,293

 

Operating Expenses:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Utility operating expenses:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Resource costs

 

 

67,965

 

 

 

88,439

 

 

 

197,512

 

 

 

225,786

 

Other operating expenses

 

 

86,204

 

 

 

87,720

 

 

 

180,700

 

 

 

171,698

 

Merger transaction costs

 

 

 

 

 

11

 

 

 

 

 

 

19,675

 

Depreciation and amortization

 

 

63,908

 

 

 

55,479

 

 

 

115,329

 

 

 

104,393

 

Taxes other than income taxes

 

 

24,742

 

 

 

22,908

 

 

 

55,720

 

 

 

54,851

 

Non-utility operating expenses:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Other operating expenses

 

 

659

 

 

 

6,332

 

 

 

2,019

 

 

 

13,687

 

Depreciation and amortization

 

 

188

 

 

 

155

 

 

 

423

 

 

 

364

 

Total operating expenses

 

 

243,666

 

 

 

261,044

 

 

 

551,703

 

 

 

590,454

 

Income from operations

 

 

34,926

 

 

 

39,768

 

 

 

117,119

 

 

 

106,839

 

Interest expense

 

 

25,625

 

 

 

25,511

 

 

 

51,972

 

 

 

51,162

 

Interest expense to affiliated trusts

 

 

208

 

 

 

351

 

 

 

478

 

 

 

708

 

Capitalized interest

 

 

(972

)

 

 

(1,101

)

 

 

(1,970

)

 

 

(2,029

)

Merger termination fee

 

 

 

 

 

 

 

 

 

 

 

(103,000

)

Other expense (income)-net

 

 

531

 

 

 

(8,268

)

 

 

149

 

 

 

(9,175

)

Income before income taxes

 

 

9,534

 

 

 

23,275

 

 

 

66,490

 

 

 

169,173

 

Income tax expense (benefit)

 

 

(7,919

)

 

 

(1,741

)

 

 

613

 

 

 

28,276

 

Net income

 

 

17,453

 

 

 

25,016

 

 

 

65,877

 

 

 

140,897

 

Net loss attributable to noncontrolling interests

 

 

 

 

 

303

 

 

 

 

 

 

216

 

Net income attributable to Avista Corp. shareholders

 

$

17,453

 

 

$

25,319

 

 

$

65,877

 

 

$

141,113

 

Weighted-average common shares outstanding

   (thousands), basic

 

 

67,481

 

 

 

65,894

 

 

 

67,360

 

 

 

65,814

 

Weighted-average common shares outstanding

   (thousands), diluted

 

 

67,589

 

 

 

65,963

 

 

 

67,485

 

 

 

65,883

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Earnings per common share attributable to Avista Corp.

   shareholders:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Basic

 

$

0.26

 

 

$

0.38

 

 

$

0.98

 

 

$

2.14

 

Diluted

 

$

0.26

 

 

$

0.38

 

 

$

0.98

 

 

$

2.14

 

 

The Accompanying Notes are an Integral Part of These Statements.

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CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

Avista Corporation

For the Three and Six Months Ended June 30

Dollars in thousands

(Unaudited)

 

 

 

Three months ended June 30,

 

 

Six months ended June 30,

 

 

 

2020

 

 

2019

 

 

2020

 

 

2019

 

Net income

 

$

17,453

 

 

$

25,016

 

 

$

65,877

 

 

$

140,897

 

Other Comprehensive Income:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Change in unfunded benefit obligation for pension and other postretirement benefit plans - net of taxes of $59, $42, $113 and $85 respectively

 

 

220

 

 

 

161

 

 

 

425

 

 

 

321

 

Total other comprehensive income

 

 

220

 

 

 

161

 

 

 

425

 

 

 

321

 

Comprehensive income

 

 

17,673

 

 

 

25,177

 

 

 

66,302

 

 

 

141,218

 

Comprehensive loss attributable to noncontrolling

   interests

 

 

 

 

 

303

 

 

 

 

 

 

216

 

Comprehensive income attributable to Avista Corporation

   shareholders

 

$

17,673

 

 

$

25,480

 

 

$

66,302

 

 

$

141,434

 

 

The Accompanying Notes are an Integral Part of These Statements.

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CONDENSED CONSOLIDATED BALANCE SHEETS

Avista Corporation

Dollars in thousands

(Unaudited)

 

 

 

June 30,

 

 

December 31,

 

 

 

2020

 

 

2019

 

Assets:

 

 

 

 

 

 

 

 

Current Assets:

 

 

 

 

 

 

 

 

Cash and cash equivalents

 

$

116,394

 

 

$

9,896

 

Accounts and notes receivable-less allowances of $6,034 and $2,419, respectively

 

 

115,241

 

 

 

166,657

 

Materials and supplies, fuel stock and stored natural gas

 

 

67,333

 

 

 

66,583

 

Regulatory assets

 

 

11,177

 

 

 

21,851

 

Other current assets

 

 

42,362

 

 

 

40,142

 

Total current assets

 

 

352,507

 

 

 

305,129

 

Net utility property

 

 

4,883,133

 

 

 

4,797,007

 

Goodwill

 

 

52,426

 

 

 

52,426

 

Non-current regulatory assets

 

 

752,090

 

 

 

670,802

 

Other property and investments-net and other non-current assets

 

 

262,468

 

 

 

257,092

 

Total assets

 

$

6,302,624

 

 

$

6,082,456

 

Liabilities and Equity:

 

 

 

 

 

 

 

 

Current Liabilities:

 

 

 

 

 

 

 

 

Accounts payable

 

$

110,675

 

 

$

110,219

 

Current portion of long-term debt

 

 

52,000

 

 

 

52,000

 

Short-term borrowings

 

 

321,000

 

 

 

185,800

 

Regulatory liabilities

 

 

49,629

 

 

 

51,715

 

Other current liabilities

 

 

123,258

 

 

 

130,979

 

Total current liabilities

 

 

656,562

 

 

 

530,713

 

Long-term debt

 

 

1,844,161

 

 

 

1,843,768

 

Long-term debt to affiliated trusts

 

 

51,547

 

 

 

51,547

 

Pensions and other postretirement benefits

 

 

204,506

 

 

 

212,006

 

Deferred income taxes

 

 

540,494

 

 

 

528,513

 

Non-current regulatory liabilities

 

 

778,826

 

 

 

775,436

 

Other non-current liabilities and deferred credits

 

 

251,490

 

 

 

201,189

 

Total liabilities

 

 

4,327,586

 

 

 

4,143,172

 

Commitments and Contingencies (See Notes to Condensed Consolidated

   Financial Statements)

 

 

 

 

 

 

 

 

Equity:

 

 

 

 

 

 

 

 

Avista Corporation Shareholders’ Equity:

 

 

 

 

 

 

 

 

Common stock, no par value; 200,000,000 shares authorized; 67,913,265 and

   67,176,996 shares issued and outstanding, respectively

 

 

1,234,901

 

 

 

1,210,741

 

Accumulated other comprehensive loss

 

 

(9,834

)

 

 

(10,259

)

Retained earnings

 

 

749,971

 

 

 

738,802

 

Total Avista Corporation shareholders’ equity

 

 

1,975,038

 

 

 

1,939,284

 

Total liabilities and equity

 

$

6,302,624

 

 

$

6,082,456

 

 

The Accompanying Notes are an Integral Part of These Statements.

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CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

Avista Corporation

For the Six Months Ended June 30

Dollars in thousands

(Unaudited)

 

 

 

2020

 

 

2019

 

Operating Activities:

 

 

 

 

 

 

 

 

Net income

 

$

65,877

 

 

$

140,897

 

Non-cash items included in net income:

 

 

 

 

 

 

 

 

Depreciation and amortization

 

 

115,752

 

 

 

104,757

 

Deferred income tax provision and investment tax credits

 

 

(8,400

)

 

 

5,577

 

Power and natural gas cost amortizations (deferrals), net

 

 

1,815

 

 

 

(47,716

)

Amortization of debt expense

 

 

1,365

 

 

 

1,338

 

Amortization of investment in exchange power

 

 

 

 

 

1,225

 

Stock-based compensation expense

 

 

2,826

 

 

 

7,009

 

Equity-related AFUDC

 

 

(3,271

)

 

 

(3,253

)

Pension and other postretirement benefit expense

 

 

16,481

 

 

 

18,040

 

Other regulatory assets and liabilities and deferred debits and credits

 

 

4,391

 

 

 

1,122

 

Change in decoupling regulatory deferral

 

 

(454

)

 

 

(5,444

)

Gain on sale of METALfx (before payment of transaction costs)

 

 

 

 

 

(6,477

)

Gain on sale of investments

 

 

(3,231

)

 

 

 

Other

 

 

9,043

 

 

 

(3,904

)

Contributions to defined benefit pension plan

 

 

(14,600

)

 

 

(14,600

)

Changes in certain current assets and liabilities:

 

 

 

 

 

 

 

 

Accounts and notes receivable

 

 

43,701

 

 

 

47,771

 

Materials and supplies, fuel stock and stored natural gas

 

 

(751

)

 

 

(7,225

)

Collateral posted for derivative instruments

 

 

(7,209

)

 

 

47,352

 

Income taxes receivable

 

 

9,106

 

 

 

517

 

Other current assets

 

 

(5,704

)

 

 

(9,300

)

Accounts payable

 

 

(29,860

)

 

 

(19,393

)

Other current liabilities

 

 

3,011

 

 

 

(5,622

)

Net cash provided by operating activities

 

 

199,888

 

 

 

252,671

 

 

 

 

 

 

 

 

 

 

Investing Activities:

 

 

 

 

 

 

 

 

Utility property capital expenditures (excluding equity-related AFUDC)

 

 

(189,480

)

 

 

(199,988

)

Issuance of notes receivable by subsidiaries

 

 

(4,343

)

 

 

(900

)

Equity and property investments

 

 

(2,097

)

 

 

(6,624

)

Proceeds from sale of METALfx (net of cash sold)

 

 

 

 

 

16,407

 

Proceeds from sale of investments

 

 

5,144

 

 

 

 

Other

 

 

(988

)

 

 

1,072

 

Net cash used in investing activities

 

 

(191,764

)

 

 

(190,033

)

 

The Accompanying Notes are an Integral Part of These Statements.

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CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (continued)

Avista Corporation

For the Six Months Ended June 30

Dollars in thousands

(Unaudited)

 

 

 

 

2020

 

 

2019

 

Financing Activities:

 

 

 

 

 

 

 

 

Net increase (decrease) in short-term borrowings

 

$

135,200

 

 

$

(21,000

)

Maturity of long-term debt and finance leases

 

 

(1,431

)

 

 

(1,330

)

Issuance of common stock, net of issuance costs

 

 

23,890

 

 

 

14,929

 

Cash dividends paid

 

 

(54,708

)

 

 

(51,153

)

Other

 

 

(4,577

)

 

 

(1,509

)

Net cash provided by (used in) financing activities

 

 

98,374

 

 

 

(60,063

)

 

 

 

 

 

 

 

 

 

Net increase in cash and cash equivalents

 

 

106,498

 

 

 

2,575

 

 

 

 

 

 

 

 

 

 

Cash and cash equivalents at beginning of period

 

 

9,896

 

 

 

14,656

 

 

 

 

 

 

 

 

 

 

Cash and cash equivalents at end of period

 

$

116,394

 

 

$

17,231

 

 

The Accompanying Notes are an Integral Part of These Statements.

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CONDENSED CONSOLIDATED STATEMENTS OF EQUITY

Avista Corporation

For the Three and Six Months Ended June 30

Dollars in thousands

(Unaudited)

 

 

 

Three months ended June 30,

 

 

Six months ended June 30,

 

 

 

2020

 

 

2019

 

 

2020

 

 

2019

 

Common Stock, Shares:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Shares outstanding at beginning of period

 

 

67,292,233

 

 

 

65,749,932

 

 

 

67,176,996

 

 

 

65,688,356

 

Shares issued

 

 

621,032

 

 

 

361,385

 

 

 

736,269

 

 

 

422,961

 

Shares outstanding at end of period

 

 

67,913,265

 

 

 

66,111,317

 

 

 

67,913,265

 

 

 

66,111,317

 

Common Stock, Amount:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Balance at beginning of period

 

$

1,209,312

 

 

$

1,140,242

 

 

$

1,210,741

 

 

$

1,136,491

 

Equity compensation expense

 

 

1,874

 

 

 

2,043

 

 

 

2,678

 

 

 

6,495

 

Issuance of common stock, net of issuance costs

 

 

23,715

 

 

 

14,739

 

 

 

23,890

 

 

 

14,929

 

Payment of minimum tax withholdings for share-based

   payment awards

 

 

 

 

 

 

 

 

(2,408

)

 

 

(891

)

Balance at end of period

 

 

1,234,901

 

 

 

1,157,024

 

 

 

1,234,901

 

 

 

1,157,024

 

Accumulated Other Comprehensive Loss:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Balance at beginning of period

 

 

(10,054

)

 

 

(7,706

)

 

 

(10,259

)

 

 

(7,866

)

Other comprehensive income

 

 

220

 

 

 

161

 

 

 

425

 

 

 

321

 

Balance at end of period

 

 

(9,834

)

 

 

(7,545

)

 

 

(9,834

)

 

 

(7,545

)

Retained Earnings:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Balance at beginning of period

 

 

759,837

 

 

 

734,774

 

 

 

738,802

 

 

 

644,595

 

Net income attributable to Avista Corporation shareholders

 

 

17,453

 

 

 

25,319

 

 

 

65,877

 

 

 

141,113

 

Cash dividends paid on common stock

 

 

(27,319

)

 

 

(25,538

)

 

 

(54,708

)

 

 

(51,153

)

Balance at end of period

 

 

749,971

 

 

 

734,555

 

 

 

749,971

 

 

 

734,555

 

Total Avista Corporation shareholders’ equity

 

 

1,975,038

 

 

 

1,884,034

 

 

 

1,975,038

 

 

 

1,884,034

 

Noncontrolling Interests:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Balance at beginning of period

 

 

 

 

 

912

 

 

 

 

 

 

825

 

Net loss attributable to noncontrolling interests

 

 

 

 

 

(303

)

 

 

 

 

 

(216

)

Deconsolidation of noncontrolling interests related to sale of METALfx

 

 

 

 

 

(609

)

 

 

 

 

 

(609

)

Balance at end of period

 

 

 

 

 

 

 

 

 

 

 

 

Total equity

 

$

1,975,038

 

 

$

1,884,034

 

 

$

1,975,038

 

 

$

1,884,034

 

Dividends declared per common share

 

$

0.4050

 

 

$

0.3875

 

 

$

0.8100

 

 

$

0.7750

 

 

The Accompanying Notes are an Integral Part of These Statements.

 

 

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NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Unaudited)

The accompanying condensed consolidated financial statements of Avista Corp. as of and for the interim periods ended June 30, 2020 and June 30, 2019 are unaudited; however, in the opinion of management, the statements reflect all adjustments necessary for a fair statement of the results for the interim periods. All such adjustments are of a normal recurring nature. The condensed consolidated financial statements have been prepared in accordance with GAAP for interim financial information and with the instructions to Form 10-Q and Rule 10-01 of Regulation S-X. The Condensed Consolidated Statements of Income for the interim periods are not necessarily indicative of the results to be expected for the full year. These condensed consolidated financial statements do not contain the detail or footnote disclosure concerning accounting policies and other matters which would be included in full fiscal year consolidated financial statements; therefore, they should be read in conjunction with the Company's audited consolidated financial statements included in the Company's Annual Report on Form 10-K for the year ended December 31, 2019 (2019 Form 10-K).

NOTE 1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

Nature of Business

Avista Corp. is primarily an electric and natural gas utility with certain other business ventures. Avista Utilities is an operating division of Avista Corp., comprising its regulated utility operations in the Pacific Northwest. Avista Utilities provides electric distribution and transmission, and natural gas distribution services in parts of eastern Washington and northern Idaho. Avista Utilities also provides natural gas distribution service in parts of northeastern and southwestern Oregon. Avista Utilities has electric generating facilities in Washington, Idaho, Oregon and Montana. Avista Utilities also supplies electricity to a small number of customers in Montana, most of whom are employees who operate the Company's Noxon Rapids generating facility.

AERC is a wholly-owned subsidiary of Avista Corp. The primary subsidiary of AERC is AEL&P, which comprises Avista Corp.'s regulated utility operations in Alaska.

Avista Capital, a wholly owned non-regulated subsidiary of Avista Corp., is the parent company of all of the subsidiary companies in the non-utility businesses, with the exception of AJT Mining Properties, Inc., which is a subsidiary of AERC. See Note 16 for business segment information. See Note 18 for discussion of the sale of METALfx, an unregulated subsidiary of the Company.

Basis of Reporting

The condensed consolidated financial statements include the assets, liabilities, revenues and expenses of the Company and its subsidiaries and other majority owned subsidiaries and variable interest entities for which the Company or its subsidiaries are the primary beneficiaries. Intercompany balances were eliminated in consolidation. The accompanying condensed consolidated financial statements include the Company’s proportionate share of utility plant and related operations resulting from its interests in jointly owned plants.

Derivative Assets and Liabilities

Derivatives are recorded as either assets or liabilities on the Condensed Consolidated Balance Sheets measured at estimated fair value.

The WUTC and the IPUC issued accounting orders authorizing Avista Corp. to offset energy commodity derivative assets or liabilities with a regulatory asset or liability. This accounting treatment is intended to defer the recognition of mark-to-market gains and losses on energy commodity transactions until the period of delivery. Realized benefits and costs result in adjustments to retail rates through PGAs, the ERM in Washington, the PCA mechanism in Idaho, and periodic general rate cases. The resulting regulatory assets associated with energy commodity derivative instruments have been concluded to be probable of recovery through future rates.

Substantially all forward contracts to purchase or sell power and natural gas are recorded as derivative assets or liabilities at estimated fair value with an offsetting regulatory asset or liability. Contracts that are not considered derivatives are accounted for on the accrual basis until they are settled or realized unless there is a decline in the fair value of the contract that is determined to be other-than-temporary.

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For interest rate swap derivatives, Avista Corp. records all mark-to-market gains and losses in each accounting period as assets and liabilities, as well as offsetting regulatory assets and liabilities, such that there is no income statement impact. The interest rate swap derivatives are risk management tools similar to energy commodity derivatives. Upon settlement of interest rate swap derivatives, the cash payments made or received are recorded as a regulatory asset or liability and are subsequently amortized as a component of interest expense over the life of the associated debt. The settled interest rate swap derivatives are also included as a part of Avista Corp.'s cost of debt calculation for ratemaking purposes.

The Company has multiple master netting agreements with a variety of entities that allow for cross-commodity netting of derivative agreements with the same counterparty (i.e. power derivatives can be netted with natural gas derivatives). In addition, some master netting agreements allow for the netting of commodity derivatives and interest rate swap derivatives for the same counterparty. The Company does not have any agreements which allow for cross-affiliate netting among multiple affiliated legal entities. The Company nets all derivative instruments when allowed by the agreement for presentation in the Condensed Consolidated Balance Sheets.

Fair Value Measurements

Fair value represents the price that would be received when selling an asset or paid to transfer a liability (an exit price) in an orderly transaction between market participants at the measurement date. Energy commodity derivative assets and liabilities, deferred compensation assets, as well as derivatives related to interest rate swaps and foreign currency exchange contracts, are reported at estimated fair value on the Condensed Consolidated Balance Sheets. See Note 11 for the Company’s fair value disclosures.

Contingencies

The Company has unresolved regulatory, legal and tax issues which have inherently uncertain outcomes. The Company accrues a loss contingency if it is probable that a liability has been incurred and the amount of the loss or impairment can be reasonably estimated. The Company also discloses loss contingencies that do not meet these conditions for accrual if there is a reasonable possibility that a material loss may be incurred. See Note 15 for further discussion of the Company's commitments and contingencies.

COVID-19

In March 2020, the Company filed an application for authorization to defer certain incremental COVID-19 related costs with the OPUC. In April and May 2020, the Company made similar filings with the IPUC and the WUTC, respectively. In Alaska, a Senate Bill was signed into law that provides for deferral and recovery of incremental COVID-19 related costs subject to approval by the RCA. The recovery of any deferred costs would be determined in future rate making proceedings. On July 7, 2020, the IPUC issued an order that allows the Company to defer certain costs related to COVID-19, net of any decreased costs and other benefits related to COVID-19. As approved by the IPUC in July, the Company plans to resume disconnections and accruing late fees for customers in its Idaho service area beginning in early August 2020. The IPUC will determine the appropriateness and prudency of any deferred expenses when the utility seeks recovery.

NOTE 2. NEW ACCOUNTING STANDARDS

ASU No. 2016-12 "Financial Instruments - Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments"

On January 1, 2020, the Company adopted ASU 2016-13, which replaces the incurred loss impairment methodology in previous GAAP with a methodology that reflects expected credit losses, and requires consideration of a broader range of reasonable and supportable information to inform credit loss estimates. The Company analyzed its financial instruments within the scope of this guidance, primarily trade receivables, and it did not have a material impact to the Company's financial statements and does not require additional disclosure in these Notes to the Condensed Consolidated Financial Statements.

ASU 2018-13 "Fair Value Measurement (Topic 820)"

In August 2018, the FASB issued ASU No. 2018-13, which amends the fair value measurement disclosure requirements of ASC 820. The requirements of this ASU include additional disclosure regarding the range and weighted average used to develop significant

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AVISTA CORPORATION

 

unobservable inputs for Level 3 fair value estimates and the elimination of certain other previously required disclosures, such as the narrative description of the valuation process for Level 3 fair value measurements. This ASU became effective on January 1, 2020 and the requirements of this ASU did not have a material impact on the Company's fair value disclosures. See Note 11 for the Company's fair value disclosures.

ASU No. 2018-14 "Compensation - Retirement Benefits - Defined Benefit Plans - General (Subtopic 715-20)"

In August 2018, the FASB issued ASU No. 2018-14, which amends ASC 715 to add, remove and/or clarify certain disclosure requirements related to defined benefit pension and other postretirement plans. The additional disclosure requirements are primarily narrative discussion of significant changes in the benefit obligations and plan assets. The removed disclosures are primarily information about accumulated other comprehensive income expected to be recognized over the next year and the effects of changes associated with assumed health care costs. This ASU is effective for periods beginning after December 15, 2021 and early adoption is permitted. The Company is in the process of evaluating this standard; however, it has determined that it will not early adopt this standard as of June 30, 2020.

NOTE 3. BALANCE SHEET COMPONENTS

Materials and Supplies, Fuel Stock and Stored Natural Gas

Inventories of materials and supplies, fuel stock and stored natural gas are recorded at average cost for our regulated operations and the lower of cost or market for our non-regulated operations and consisted of the following as of June 30, 2020 and December 31, 2019 (dollars in thousands):

 

 

 

June 30,

 

 

December 31,

 

 

 

2020

 

 

2019

 

Materials and supplies

 

$

48,867

 

 

$

47,402

 

Fuel stock

 

 

5,208

 

 

 

4,875

 

Stored natural gas

 

 

13,258

 

 

 

14,306

 

Total

 

$

67,333

 

 

$

66,583

 

 

Other Current Assets

Other current assets consisted of the following as of June 30, 2020 and December 31, 2019 (dollars in thousands):

 

 

 

June 30,

 

 

December 31,

 

 

 

2020

 

 

2019

 

Collateral posted for derivative instruments after netting with outstanding

   derivative liabilities

 

$

 

 

$

4,434

 

Prepayments

 

 

21,813

 

 

 

19,652

 

Income taxes receivable

 

 

1,941

 

 

 

11,047

 

Other

 

 

18,608

 

 

 

5,009

 

Total

 

$

42,362

 

 

$

40,142

 

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Net Utility Property

Net utility property consisted of the following as of June 30, 2020 and December 31, 2019 (dollars in thousands):

 

 

 

June 30,

 

 

December 31,

 

 

 

2020

 

 

2019

 

Utility plant in service

 

$

6,613,219

 

 

$

6,462,993

 

Construction work in progress

 

 

195,937

 

 

 

164,941

 

Total

 

 

6,809,156

 

 

 

6,627,934

 

Less: Accumulated depreciation and amortization

 

 

1,926,023

 

 

 

1,830,927

 

Total net utility property

 

$

4,883,133

 

 

$

4,797,007

 

 

Other Property and Investments-Net and Other Non-Current Assets

Other property and investments-net and other non-current assets consisted of the following as of June 30, 2020 and December 31, 2019 (dollars in thousands):

 

 

 

June 30,

 

 

December 31,

 

 

 

2020

 

 

2019

 

Operating lease ROU assets

 

$

72,588

 

 

$

69,746

 

Finance lease ROU assets

 

 

49,159

 

 

 

50,980

 

Non-utility property

 

 

26,774

 

 

 

27,159

 

Equity investments

 

 

51,748

 

 

 

51,258

 

Investment in affiliated trust

 

 

11,547

 

 

 

11,547

 

Notes receivable

 

 

16,375

 

 

 

14,060

 

Deferred compensation assets

 

 

8,435

 

 

 

8,948

 

Other

 

 

25,842

 

 

 

23,394

 

Total

 

$

262,468

 

 

$

257,092

 

 

Other Current Liabilities

Other current liabilities consisted of the following as of June 30, 2020 and December 31, 2019 (dollars in thousands):

 

 

 

June 30,

2020

 

 

December 31,

2019

 

Accrued taxes other than income taxes

 

$

38,734

 

 

$

36,965

 

Employee paid time off accruals

 

 

25,728

 

 

 

22,343

 

Accrued interest

 

 

16,226

 

 

 

16,486

 

Current portion of pensions and other postretirement benefits

 

 

11,700

 

 

 

8,826

 

Income taxes payable

 

 

 

 

 

298

 

Derivative liabilities

 

 

3,064

 

 

 

10,928

 

Other current liabilities

 

 

27,806

 

 

 

35,133

 

Total other current liabilities

 

$

123,258

 

 

$

130,979

 

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Other Non-Current Liabilities and Deferred Credits

Other non-current liabilities and deferred credits consisted of the following as of June 30, 2020 and December 31, 2019 (dollars in thousands):

 

 

 

June 30,

2020

 

 

December 31,

2019

 

Operating lease liabilities

 

$

70,330

 

 

$

65,565

 

Finance lease liabilities

 

 

50,283

 

 

 

51,750

 

Deferred investment tax credits

 

 

30,162

 

 

 

30,444

 

Asset retirement obligations

 

 

20,236

 

 

 

20,338

 

Derivative liabilities

 

 

67,038

 

 

 

19,685

 

Other

 

 

13,441

 

 

 

13,407

 

Total

 

$

251,490

 

 

$

201,189

 

 

Regulatory Assets and Liabilities

Regulatory assets and liabilities consisted of the following as of June 30, 2020 and December 31, 2019 (dollars in thousands):

 

 

 

June 30, 2020

 

 

December 31, 2019

 

 

 

Current

 

 

Non-Current

 

 

Current

 

 

Non-Current

 

Regulatory Assets

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Energy commodity derivatives

 

$

309

 

 

$

 

 

$

6,310

 

 

$

264

 

Decoupling surcharge

 

 

10,345

 

 

 

18,514

 

 

 

12,098

 

 

 

14,806

 

Pension and other postretirement benefit plans

 

 

 

 

 

203,471

 

 

 

 

 

 

208,754

 

Interest rate swaps

 

 

 

 

 

244,672

 

 

 

 

 

 

168,594

 

Deferred income taxes

 

 

 

 

 

98,879

 

 

 

 

 

 

95,752

 

Settlement with Coeur d'Alene Tribe

 

 

 

 

 

40,677

 

 

 

 

 

 

41,332

 

AFUDC above FERC allowed rate

 

 

 

 

 

41,912

 

 

 

 

 

 

40,749

 

Demand side management programs

 

 

 

 

 

6,538

 

 

 

 

 

 

12,170

 

Utility plant to be abandoned

 

 

 

 

 

30,700

 

 

 

 

 

 

31,291

 

Other regulatory assets

 

 

523

 

 

 

66,727

 

 

 

3,443

 

 

 

57,090

 

Total regulatory assets

 

$

11,177

 

 

$

752,090

 

 

$

21,851

 

 

$

670,802

 

Regulatory Liabilities

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Income tax related liabilities

 

$

13,335

 

 

$

400,564

 

 

$

23,803

 

 

$

407,549

 

Deferred natural gas costs

 

 

2,778

 

 

 

 

 

 

3,189

 

 

 

 

Deferred power costs

 

 

21,692

 

 

 

20,112

 

 

 

14,155

 

 

 

23,544

 

Decoupling rebate

 

 

796

 

 

 

3,359

 

 

 

255

 

 

 

2,398

 

Provision for rate refund (Washington remand case)

 

 

7,339

 

 

 

 

 

 

3,565

 

 

 

 

Utility plant retirement costs

 

 

 

 

 

322,138

 

 

 

 

 

 

312,403

 

Interest rate swaps

 

 

 

 

 

15,773

 

 

 

 

 

 

17,088

 

Other regulatory liabilities

 

 

3,689

 

 

 

16,880

 

 

 

6,748

 

 

 

12,454

 

Total regulatory liabilities

 

$

49,629

 

 

$

778,826

 

 

$

51,715

 

 

$

775,436

 

 

NOTE 4. REVENUE

ASC 606 defines the core principle of the revenue recognition model is that an entity should identify the various performance obligations in a contract, allocate the transaction price among the performance obligations and recognize revenue when (or as) the entity satisfies each performance obligation.

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Utility Revenues

Revenue from Contracts with Customers

General

The majority of Avista Corp.’s revenue is from rate-regulated sales of electricity and natural gas to retail customers, which has two performance obligations, (1) having service available for a specified period (typically a month at a time) and (2) the delivery of energy to customers. The total energy price generally has a fixed component (basic charge) related to having service available and a usage-based component, related to the delivery and consumption of energy. The commodity is sold and/or delivered to and consumed by the customer simultaneously, and the provisions of the relevant utility commission authorization determine the charges the Company may bill the customer. Given that all revenue recognition criteria are met upon the delivery of energy to customers, revenue is recognized immediately at that time.

Revenues from contracts with customers are presented in the Condensed Consolidated Statements of Income in the line item "Utility revenues, exclusive of alternative revenue programs."

Non-Derivative Wholesale Contracts

The Company has certain wholesale contracts which are not accounted for as derivatives and, accordingly, are within the scope of ASC 606 and considered revenue from contracts with customers. Revenue is recognized as energy is delivered to the customer or the service is available for a specified period of time, consistent with the discussion of rate-regulated sales above.

Alternative Revenue Programs (Decoupling)

ASC 606 retained existing GAAP associated with alternative revenue programs, which specified that alternative revenue programs are contracts between an entity and a regulator of utilities, not a contract between an entity and a customer. GAAP requires that an entity present revenue arising from alternative revenue programs separately from revenues arising from contracts with customers on the face of the Condensed Consolidated Statements of Income. The Company's decoupling mechanisms (also known as a FCA in Idaho) qualify as alternative revenue programs. Decoupling revenue deferrals are recognized in the Condensed Consolidated Statements of Income during the period they occur (i.e. during the period of revenue shortfall or excess due to fluctuations in customer usage), subject to certain limitations, and a regulatory asset or liability is established that will be surcharged or rebated to customers in future periods. GAAP requires that for any alternative revenue program, like decoupling, the revenue must be expected to be collected from customers within 24 months of the deferral to qualify for recognition in the current period Condensed Consolidated Statement of Income. Any amounts included in the Company's decoupling program that are not expected to be collected from customers within 24 months are not recorded in the financial statements until the period in which revenue recognition criteria are met. The amounts expected to be collected from customers within 24 months represents an estimate that must be made by the Company on an ongoing basis due to it being based on the volumes of electric and natural gas sold to customers on a go-forward basis.

Derivative Revenue

Most wholesale electric and natural gas transactions (including both physical and financial transactions), and the sale of fuel are considered derivatives, which are specifically scoped out of ASC 606. As such, these revenues are disclosed separately from revenue from contracts with customers. Revenue is recognized for these items upon the settlement/expiration of the derivative contract. Derivative revenue includes those transactions that are entered into and settled within the same month.

Other Utility Revenue

Other utility revenue includes rent, revenues from the pre-apprentice training school, sales of materials, late fees and other charges that do not represent contracts with customers. Other utility revenue also includes the provision for earnings sharing and the deferral and amortization of refunds to customers associated with the TCJA. This revenue is scoped out of ASC 606, as this revenue does not represent items where a customer is a party that has contracted with the Company to obtain goods or services that are an output of the

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Company’s ordinary activities in exchange for consideration. As such, these revenues are presented separately from revenue from contracts with customers.

Other Considerations for Utility Revenues

Gross Versus Net Presentation

Revenues and resource costs from Avista Utilities’ settled energy contracts that are “booked out” (not physically delivered) are reported on a net basis as part of derivative revenues.

Utility-related taxes collected from customers (primarily state excise taxes and city utility taxes) are taxes that are imposed on Avista Utilities as opposed to being imposed on its customers; therefore, Avista Utilities is the taxpayer and records these transactions on a gross basis in revenue from contracts with customers and operating expense (taxes other than income taxes). The utility-related taxes collected from customers at AEL&P are imposed on the customers rather than AEL&P; therefore, the customers are the taxpayers and AEL&P is acting as their agent. As such, these transactions at AEL&P are presented on a net basis within revenue from contracts with customers.

Utility-related taxes that were included in revenue from contracts with customers were as follows for the three and six months ended June 30 (dollars in thousands):

 

 

Three months ended June 30,

 

 

Six months ended June 30,

 

 

2020

 

 

2019

 

 

2020

 

 

2019

 

Utility-related taxes

$

12,879

 

 

$

12,688

 

 

$

31,578

 

 

$

31,777

 

 

Non-Utility Revenues

Revenue from Contracts with Customers

Non-utility revenue from contracts with customers is derived from contracts with one performance obligation. Prior to its sale in April 2019 (See Note 18 for further discussion on the sale of METALfx), METALfx had one performance obligation, the delivery of a product, and revenues were recognized when the risk of loss transferred to the customer, which occurred when products were shipped. The Steam Plant Kitchen and Brew Pub serves food and beverages to customers, its one performance obligation, and recognizes revenues at the time of service to the customer.

Significant Judgments and Unsatisfied Performance Obligations

The only significant judgments involving revenue recognition are estimates surrounding unbilled revenue and receivables from contracts with customers and estimates surrounding the amount of decoupling revenues that will be collected from customers within 24 months (discussed above).

The Company has certain capacity arrangements, where the Company has a contractual obligation to provide either electric or natural gas capacity to its customers for a fixed fee. Most of these arrangements are paid for in arrears by the customers and do not result in deferred revenue and only result in receivables from the customers. The Company does have one capacity agreement where the customer makes payments throughout the year, and depending on the timing of the customer payments, it can result in an immaterial amount of deferred revenue or a receivable from the customer. As of June 30, 2020, the Company estimates it had unsatisfied capacity performance obligations of $3.5 million, which will be recognized as revenue in future periods as the capacity is provided to the customers. These performance obligations are not reflected in the financial statements, as the Company has not received payment for these services.

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Disaggregation of Total Operating Revenue

The following table disaggregates total operating revenue by segment and source for the three and six months ended June 30 (dollars in thousands):

 

 

 

Three months ended

June 30,

 

 

Six months ended

June 30,

 

 

 

2020

 

 

2019

 

 

2020

 

 

2019

 

Avista Utilities

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Revenue from contracts with customers

 

$

235,405

 

 

$

231,605

 

 

$

587,034

 

 

$

585,907

 

Derivative revenues

 

 

24,211

 

 

 

42,128

 

 

 

55,285

 

 

 

66,255

 

Alternative revenue programs

 

 

4,362

 

 

 

9,725

 

 

 

(51

)

 

 

5,067

 

Deferrals and amortizations for rate refunds to

   customers

 

 

2,080

 

 

 

2,512

 

 

 

(525

)

 

 

4,647

 

Other utility revenues

 

 

2,281

 

 

 

3,838

 

 

 

3,801

 

 

 

5,634

 

Total Avista Utilities

 

 

268,339

 

 

 

289,808

 

 

 

645,544

 

 

 

667,510

 

AEL&P

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Revenue from contracts with customers

 

 

9,978

 

 

 

8,620

 

 

 

22,104

 

 

 

19,356

 

Deferrals and amortizations for rate refunds to

   customers

 

 

(47

)

 

 

(47

)

 

 

(95

)

 

 

(95

)

Other utility revenues

 

 

67

 

 

 

170

 

 

 

191

 

 

 

363

 

Total AEL&P

 

 

9,998

 

 

 

8,743

 

 

 

22,200

 

 

 

19,624

 

Other

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Revenue from contracts with customers

 

 

4

 

 

 

2,024

 

 

 

518

 

 

 

9,671

 

Other revenues

 

 

251

 

 

 

237

 

 

 

560

 

 

 

488

 

Total other

 

 

255

 

 

 

2,261

 

 

 

1,078

 

 

 

10,159

 

Total operating revenues

 

$

278,592

 

 

$

300,812

 

 

$

668,822

 

 

$

697,293

 

 

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Utility Revenue from Contracts with Customers by Type and Service

The following table disaggregates revenue from contracts with customers associated with the Company's electric operations for the three and six months ended June 30 (dollars in thousands):

 

 

 

2020

 

 

2019

 

 

 

Avista

Utilities

 

 

AEL&P

 

 

Total Utility

 

 

Avista

Utilities

 

 

AEL&P

 

 

Total Utility

 

Three months ended June 30:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

ELECTRIC OPERATIONS

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Revenue from contracts with customers

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Residential

 

$

78,760

 

 

$

4,190

 

 

$

82,950

 

 

$

72,886

 

 

$

3,724

 

 

$

76,610

 

Commercial and governmental

 

 

68,785

 

 

 

5,729

 

 

 

74,514

 

 

 

76,375

 

 

 

4,837

 

 

 

81,212

 

Industrial

 

 

24,816

 

 

 

 

 

 

24,816

 

 

 

26,245

 

 

 

 

 

 

26,245

 

Public street and highway lighting

 

 

1,846

 

 

 

59

 

 

 

1,905

 

 

 

1,897

 

 

 

59

 

 

 

1,956

 

Total retail revenue

 

 

174,207

 

 

 

9,978

 

 

 

184,185

 

 

 

177,403

 

 

 

8,620

 

 

 

186,023

 

Transmission

 

 

4,409

 

 

 

 

 

 

4,409

 

 

 

4,250

 

 

 

 

 

 

4,250

 

Other revenue from contracts with

   customers

 

 

3,415

 

 

 

 

 

 

3,415

 

 

 

4,379

 

 

 

 

 

 

4,379

 

Total revenue from

   contracts with customers

 

$

182,031

 

 

$

9,978

 

 

$

192,009

 

 

$

186,032

 

 

$

8,620

 

 

$

194,652

 

NATURAL GAS OPERATIONS

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Revenue from contracts with customers

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Residential

 

$

34,826

 

 

$

 

 

$

34,826

 

 

$

27,937

 

 

$

 

 

$

27,937

 

Commercial

 

 

14,142

 

 

 

 

 

 

14,142

 

 

 

13,369

 

 

 

 

 

 

13,369

 

Industrial and interruptible

 

 

1,543

 

 

 

 

 

 

1,543

 

 

 

1,103

 

 

 

 

 

 

1,103

 

Total retail revenue

 

 

50,511

 

 

 

 

 

 

50,511

 

 

 

42,409

 

 

 

 

 

 

42,409

 

Transportation

 

 

1,738

 

 

 

 

 

 

1,738

 

 

 

2,039

 

 

 

 

 

 

2,039

 

Other revenue from contracts with

   customers

 

 

1,125

 

 

 

 

 

 

1,125

 

 

 

1,125

 

 

 

 

 

 

1,125

 

Total revenue from contracts

   with customers

 

$

53,374

 

 

$

 

 

$

53,374

 

 

$

45,573

 

 

$

 

 

$

45,573

 

Six months ended June 30:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

ELECTRIC OPERATIONS

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Revenue from contracts with customers

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Residential

 

$

186,737

 

 

$

10,045

 

 

$

196,782

 

 

$

188,279

 

 

$

9,576

 

 

$

197,855

 

Commercial and governmental

 

 

147,634

 

 

 

11,938

 

 

 

159,572

 

 

 

155,621

 

 

 

9,658

 

 

 

165,279

 

Industrial

 

 

49,527

 

 

 

 

 

 

49,527

 

 

 

51,493

 

 

 

 

 

 

51,493

 

Public street and highway lighting

 

 

3,629

 

 

 

121

 

 

 

3,750

 

 

 

3,800

 

 

 

122

 

 

 

3,922

 

Total retail revenue

 

 

387,527

 

 

 

22,104

 

 

 

409,631

 

 

 

399,193

 

 

 

19,356

 

 

 

418,549

 

Transmission

 

 

8,183

 

 

 

 

 

 

8,183

 

 

 

9,402

 

 

 

 

 

 

9,402

 

Other revenue from contracts with

   customers

 

 

8,705

 

 

 

 

 

 

8,705

 

 

 

12,573

 

 

 

 

 

 

12,573

 

Total electric revenue from contracts

   with customers

 

$

404,415

 

 

$

22,104

 

 

$

426,519

 

 

$

421,168

 

 

$

19,356

 

 

$

440,524

 

NATURAL GAS OPERATIONS

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Revenue from contracts with customers

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Residential

 

$

118,998

 

 

$

 

 

$

118,998

 

 

$

105,272

 

 

$

 

 

$

105,272

 

Commercial

 

 

53,544

 

 

 

 

 

 

53,544

 

 

 

49,964

 

 

 

 

 

 

49,964

 

Industrial and interruptible

 

 

3,737

 

 

 

 

 

 

3,737

 

 

 

2,730

 

 

 

 

 

 

2,730

 

Total retail revenue

 

 

176,279

 

 

 

 

 

 

176,279

 

 

 

157,966

 

 

 

 

 

 

157,966

 

Transportation

 

 

4,090

 

 

 

 

 

 

4,090

 

 

 

4,523

 

 

 

 

 

 

4,523

 

Other revenue from contracts with

   customers

 

 

2,250

 

 

 

 

 

 

2,250

 

 

 

2,250

 

 

 

 

 

 

2,250

 

Total natural gas revenue from

   contracts with customers

 

$

182,619

 

 

$

 

 

$

182,619

 

 

$

164,739

 

 

$

 

 

$

164,739

 

 

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NOTE 5. DERIVATIVES AND RISK MANAGEMENT

Energy Commodity Derivatives

Avista Corp. is exposed to market risks relating to changes in electricity and natural gas commodity prices and certain other fuel prices. Market risk is, in general, the risk of fluctuation in the market price of the commodity being traded and is influenced primarily by supply and demand. Market risk includes the fluctuation in the market price of associated derivative commodity instruments. Avista Corp. utilizes derivative instruments, such as forwards, futures, swap derivatives and options, in order to manage the various risks relating to these commodity price exposures. Avista Corp. has an energy resources risk policy and control procedures to manage these risks.

As part of Avista Corp.'s resource procurement and management operations in the electric business, Avista Corp. engages in an ongoing process of resource optimization, which involves the economic selection from available energy resources to serve Avista Corp.'s load obligations and the use of these resources to capture available economic value through wholesale market transactions. These include sales and purchases of electric capacity and energy, fuel for electric generation, and derivative contracts related to capacity, energy and fuel. Such transactions are part of the process of matching resources with load obligations and hedging a portion of the related financial risks. These transactions range from terms of intra-hour up to multiple years.

As part of its resource procurement and management of its natural gas business, Avista Corp. makes continuing projections of its natural gas loads and assesses available natural gas resources including natural gas storage availability. Natural gas resource planning typically includes peak requirements, low and average monthly requirements and delivery constraints from natural gas supply locations to Avista Corp.’s distribution system. However, daily variations in natural gas demand can be significantly different than monthly demand projections. On the basis of these projections, Avista Corp. plans and executes a series of transactions to hedge a portion of its projected natural gas requirements through forward market transactions and derivative instruments. These transactions may extend as much as three natural gas operating years (November through October) into the future. Avista Corp. also leaves a significant portion of its natural gas supply requirements unhedged for purchase in short-term and spot markets.

Avista Corp. plans for sufficient natural gas delivery capacity to serve its retail customers for a theoretical peak day event. Avista Corp. generally has more pipeline and storage capacity than what is needed during periods other than a peak-day. Avista Corp. optimizes its natural gas resources by using market opportunities to generate economic value that helps mitigate fixed costs. Avista Corp. also optimizes its natural gas storage capacity by purchasing and storing natural gas when prices are traditionally lower, typically in the summer, and withdrawing during higher priced months, typically during the winter. However, if market conditions and prices indicate that Avista Corp. should buy or sell natural gas at other times during the year, Avista Corp. engages in optimization transactions to capture value in the marketplace. Natural gas optimization activities include, but are not limited to, wholesale market sales of surplus natural gas supplies, purchases and sales of natural gas to optimize use of pipeline and storage capacity, and participation in the transportation capacity release market.

The following table presents the underlying energy commodity derivative volumes as of June 30, 2020 that are expected to be delivered in each respective year (in thousands of MWhs and mmBTUs):

 

 

 

Purchases

 

 

Sales

 

 

 

Electric Derivatives

 

 

Gas Derivatives

 

 

Electric Derivatives

 

 

Gas Derivatives

 

Year

 

Physical

(1)

MWh

 

 

Financial

(1)

MWh

 

 

Physical

(1)

mmBTUs

 

 

Financial

(1)

mmBTUs

 

 

Physical

(1)

MWh

 

 

Financial

(1)

MWh

 

 

Physical

(1)

mmBTUs

 

 

Financial

(1)

mmBTUs

 

Remainder 2020

 

 

29

 

 

 

329

 

 

 

9,325

 

 

 

54,560

 

 

 

71

 

 

 

802

 

 

 

1,441

 

 

 

21,460

 

2021

 

 

 

 

 

123

 

 

 

5,480

 

 

 

46,425

 

 

 

 

 

 

246

 

 

 

1,940

 

 

 

30,745

 

2022

 

 

 

 

 

 

 

 

450

 

 

 

11,300

 

 

 

 

 

 

 

 

 

 

 

 

4,500

 

2023

 

 

 

 

 

 

 

 

 

 

 

900

 

 

 

 

 

 

 

 

 

 

 

 

 

 

As of June 30, 2020, there are 0 expected deliveries of energy commodity derivatives after 2023.

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The following table presents the underlying energy commodity derivative volumes as of December 31, 2019 that are expected to be delivered in each respective year (in thousands of MWhs and mmBTUs):

 

 

 

Purchases

 

 

Sales

 

 

 

Electric Derivatives

 

 

Gas Derivatives

 

 

Electric Derivatives

 

 

Gas Derivatives

 

Year

 

Physical

(1)

MWh

 

 

Financial

(1)

MWh

 

 

Physical

(1)

mmBTUs

 

 

Financial

(1)

mmBTUs

 

 

Physical

(1)

MWh

 

 

Financial

(1)

MWh

 

 

Physical

(1)

mmBTUs

 

 

Financial

(1)

mmBTUs

 

2020

 

 

2

 

 

 

442

 

 

 

9,813

 

 

 

78,803

 

 

 

133

 

 

 

1,724

 

 

 

2,984

 

 

 

37,848

 

2021

 

 

 

 

 

 

 

 

153

 

 

 

25,523

 

 

 

 

 

 

246

 

 

 

1,040

 

 

 

13,108

 

2022

 

 

 

 

 

 

 

 

225

 

 

 

4,725

 

 

 

 

 

 

 

 

 

 

 

 

675

 

 

As of December 31, 2019, there are 0 expected deliveries of energy commodity derivatives after 2022.

(1)

Physical transactions represent commodity transactions in which Avista Corp. will take or make delivery of either electricity or natural gas; financial transactions represent derivative instruments with delivery of cash in the amount of the benefit or cost but with no physical delivery of the commodity, such as futures, swap derivatives, options, or forward contracts.

The electric and natural gas derivative contracts above will be included in either power supply costs or natural gas supply costs during the period they are scheduled to be delivered and will be included in the various deferral and recovery mechanisms (ERM, PCA and PGAs), or in the general rate case process, and are expected to be collected through retail rates from customers.

Foreign Currency Exchange Derivatives

A significant portion of Avista Corp.’s natural gas supply (including fuel for power generation) is obtained from Canadian sources. Most of those transactions are executed in U.S. dollars, which avoids foreign currency risk. A portion of Avista Corp.’s short-term natural gas transactions and long-term Canadian transportation contracts are committed based on Canadian currency prices. The short-term natural gas transactions are settled within 60 days with U.S. dollars. Avista Corp. hedges a portion of the foreign currency risk by purchasing Canadian currency exchange derivatives when such commodity transactions are initiated. The foreign currency exchange derivatives and the unhedged foreign currency risk have not had a material effect on Avista Corp.’s financial condition, results of operations or cash flows and these differences in cost related to currency fluctuations are included with natural gas supply costs for ratemaking.

The following table summarizes the foreign currency exchange derivatives that Avista Corp. has outstanding as of June 30, 2020 and December 31, 2019 (dollars in thousands):

 

 

 

June 30,

2020

 

 

December 31,

2019

 

Number of contracts

 

 

19

 

 

 

20

 

Notional amount (in United States dollars)

 

$

4,901

 

 

$

5,932

 

Notional amount (in Canadian dollars)

 

 

6,626

 

 

 

7,828

 

 

 

 

 

 

 

 

 

 

 

Interest Rate Swap Derivatives

Avista Corp. is affected by fluctuating interest rates related to a portion of its existing debt, and future borrowing requirements. Avista Corp. hedges a portion of its interest rate risk with financial derivative instruments, which may include interest rate swap derivatives and U.S. Treasury lock agreements. These interest rate swap derivatives and U.S. Treasury lock agreements are considered economic hedges against fluctuations in future cash flows associated with anticipated debt issuances.

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The following table summarizes the unsettled interest rate swap derivatives that Avista Corp. has outstanding as of June 30, 2020 and December 31, 2019 (dollars in thousands):

 

Balance Sheet Date

 

Number of

Contracts

 

 

Notional

Amount

 

 

Mandatory

Cash Settlement

Date

June 30, 2020

 

 

4

 

 

 

45,000

 

 

2021

 

 

 

11

 

 

 

120,000

 

 

2022

 

 

 

1

 

 

 

10,000

 

 

2023

December 31, 2019

 

 

7

 

 

 

70,000

 

 

2020

 

 

 

3

 

 

 

35,000

 

 

2021

 

 

 

10

 

 

 

110,000

 

 

2022

 

The fair value of outstanding interest rate swap derivatives can vary significantly from period to period depending on the total notional amount of swap derivatives outstanding and fluctuations in market interest rates compared to the interest rates fixed by the swaps. Avista Corp. is required to make cash payments to settle the interest rate swap derivatives when the fixed rates are higher than prevailing market rates at the date of settlement. Conversely, Avista Corp. receives cash to settle its interest rate swap derivatives when prevailing market rates at the time of settlement exceed the fixed swap rates.

In connection with the pricing of first mortgage bonds that are expected to be issued during the third quarter, effective June 30, 2020 the Company settled 7 interest rate swap derivatives (notional aggregate amount of $70.0 million), for a net amount of $33.5 million. The Company paid this amount in July 2020. See Note 1 for the regulatory treatment of settled interest rate swaps.

Summary of Outstanding Derivative Instruments

The amounts recorded on the Condensed Consolidated Balance Sheet as of June 30, 2020 and December 31, 2019 reflect the offsetting of derivative assets and liabilities where a legal right of offset exists.

The following table presents the fair values and locations of derivative instruments recorded on the Condensed Consolidated Balance Sheet as of June 30, 2020 (in thousands):

 

 

 

Fair Value

 

Derivative and Balance Sheet Location

 

Gross

Asset

 

 

Gross

Liability

 

 

Collateral

Netted

 

 

Net Asset

(Liability)

on Balance

Sheet

 

Foreign currency exchange derivatives

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Other current liabilities

 

$

7

 

 

$

(25

)

 

$

 

 

$

(18

)

Interest rate swap derivatives

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Other non-current liabilities and deferred credits

 

 

 

 

 

(78,018

)

 

 

10,980

 

 

 

(67,038

)

Energy commodity derivatives

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Other current assets

 

 

17,359

 

 

 

(14,604

)

 

 

(2,116

)

 

 

639

 

Other property and investments-net and other non-current assets

 

 

2,701

 

 

 

(1,543

)

 

 

(853

)

 

 

305

 

Other current liabilities

 

 

12,827

 

 

 

(15,891

)

 

 

 

 

 

(3,064

)

Other non-current liabilities and deferred credits

 

 

2,009

 

 

 

(2,017

)

 

 

 

 

 

(8

)

Total derivative instruments recorded on the balance sheet

 

$

34,903

 

 

$

(112,098

)

 

$

8,011

 

 

$

(69,184

)

 

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The following table presents the fair values and locations of derivative instruments recorded on the Condensed Consolidated Balance Sheet as of December 31, 2019 (in thousands):

 

 

 

Fair Value

 

Derivative and Balance Sheet Location

 

Gross

Asset

 

 

Gross

Liability

 

 

Collateral

Netted

 

 

Net Asset

(Liability)

on Balance

Sheet

 

Foreign currency exchange derivatives

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Other current assets

 

$

97

 

 

$

 

 

$

 

 

$

97

 

Interest rate swap derivatives

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Other current assets

 

 

589

 

 

 

 

 

 

 

 

 

589

 

Other current liabilities

 

 

238

 

 

 

(9,379

)

 

 

1,316

 

 

 

(7,825

)

Other non-current liabilities and deferred credits

 

 

725

 

 

 

(24,677

)

 

 

5,454

 

 

 

(18,498

)

Energy commodity derivatives

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Other current assets

 

 

416

 

 

 

(245

)

 

 

 

 

 

171

 

Other property and investments-net and other non-current assets

 

 

6,369

 

 

 

(5,446

)

 

 

 

 

 

923

 

Other current liabilities

 

 

34,760

 

 

 

(41,241

)

 

 

3,378

 

 

 

(3,103

)

Other non-current liabilities and deferred credits

 

 

28

 

 

 

(1,215

)

 

 

 

 

 

(1,187

)

Total derivative instruments recorded on the balance sheet

 

$

43,222

 

 

$

(82,203

)

 

$

10,148

 

 

$

(28,833

)

 

Exposure to Demands for Collateral

Avista Corp.'s derivative contracts often require collateral (in the form of cash or letters of credit) or other credit enhancements, or reductions or terminations of a portion of the contract through cash settlement. In the event of a downgrade in Avista Corp.'s credit ratings or changes in market prices, additional collateral may be required. In periods of price volatility, the level of exposure can change significantly. As a result, sudden and significant demands may be made against Avista Corp.'s credit facilities and cash. Avista Corp. actively monitors the exposure to possible collateral calls and takes steps to mitigate capital requirements.

The following table presents Avista Corp.'s collateral outstanding related to its derivative instruments as of June 30, 2020 and December 31, 2019 (in thousands):

 

 

 

June 30,

 

 

December 31,

 

 

 

2020

 

 

2019

 

Energy commodity derivatives

 

 

 

 

 

 

 

 

Cash collateral posted

 

$

 

 

$

7,812

 

Letters of credit outstanding

 

 

15,300

 

 

 

17,400

 

Balance sheet offsetting (cash collateral against net derivative positions)

 

 

(2,969

)

 

 

3,378

 

Interest rate swap derivatives

 

 

 

 

 

 

 

 

Cash collateral posted

 

 

10,980

 

 

 

6,770

 

Balance sheet offsetting (cash collateral against net derivative positions)

 

 

10,980

 

 

 

6,770

 

 

Certain of Avista Corp.’s derivative instruments contain provisions that require Avista Corp. to maintain an "investment grade" credit rating from the major credit rating agencies. If Avista Corp.’s credit ratings were to fall below "investment grade," it would be in violation of these provisions, and the counterparties to the derivative instruments could request immediate payment or demand immediate and ongoing collateralization on derivative instruments in net liability positions.

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The following table presents the aggregate fair value of all derivative instruments with credit-risk-related contingent features that are in a liability position and the amount of additional collateral Avista Corp. could be required to post as of June 30, 2020 and December 31, 2019 (in thousands):

 

 

 

June 30,

 

 

December 31,

 

 

 

2020

 

 

2019

 

Energy commodity derivatives

 

 

 

 

 

 

 

 

Liabilities with credit-risk-related contingent features

 

$

25

 

 

$

814

 

Additional collateral to post

 

 

25

 

 

 

814

 

Interest rate swap derivatives

 

 

 

 

 

 

 

 

Liabilities with credit-risk-related contingent features

 

 

78,018

 

 

 

34,056

 

Additional collateral to post

 

 

67,038

 

 

 

26,912

 

 

NOTE 6. PENSION PLANS AND OTHER POSTRETIREMENT BENEFIT PLANS

Avista Utilities

Avista Utilities’ maintained the same pension and other postretirement plans during the six months ended June 30, 2020 as those described as of December 31, 2019. The Company’s funding policy is to contribute at least the minimum amounts that are required to be funded under the Employee Retirement Income Security Act, but not more than the maximum amounts that are currently deductible for income tax purposes. The Company contributed $14.6 million in cash to the pension plan for the six months ended June 30, 2020 and it expects to contribute a total of $22 million in 2020.

The Company uses a December 31 measurement date for its defined benefit pension and other postretirement benefit plans. The following table sets forth the components of net periodic benefit costs for the six months ended June 30 (dollars in thousands):

 

 

 

Pension Benefits

 

 

Other Postretirement Benefits

 

 

 

2020

 

 

2019

 

 

2020

 

 

2019

 

Three months ended June 30:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Service cost

 

$

5,550

 

 

$

4,948

 

 

$

980

 

 

$

753

 

Interest cost

 

 

6,967

 

 

 

7,100

 

 

 

1,524

 

 

 

1,164

 

Expected return on plan assets

 

 

(8,625

)

 

 

(7,953

)

 

 

(590

)

 

 

(611

)

Amortization of prior service cost

 

 

75

 

 

 

75

 

 

 

(275

)

 

 

(275

)

Net loss recognition

 

 

1,679

 

 

 

2,426

 

 

 

1,243

 

 

 

1,329

 

Net periodic benefit cost

 

$

5,646

 

 

$

6,596

 

 

$

2,882

 

 

$

2,360

 

Six months ended June 30:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Service cost

 

$

11,096

 

 

$

9,822

 

 

$

1,959

 

 

$

1,525

 

Interest cost

 

 

13,938

 

 

 

14,238

 

 

 

3,039

 

 

 

2,536

 

Expected return on plan assets

 

 

(17,750

)

 

 

(15,768

)

 

 

(1,220

)

 

 

(1,329

)

Amortization of prior service cost

 

 

150

 

 

 

150

 

 

 

(550

)

 

 

(550

)

Net loss recognition

 

 

3,333

 

 

 

4,841

 

 

 

2,486

 

 

 

2,575

 

Net periodic benefit cost

 

$

10,767

 

 

$

13,283

 

 

$

5,714

 

 

$

4,757

 

 

Total service costs in the table above are recorded to the same accounts as labor expense. Labor and benefits expense is recorded to various projects based on whether the work is a capital project or an operating expense. Approximately 40 percent of all labor and benefits is capitalized to utility property and 60 percent is expensed to utility other operating expenses.

The non-service portion of costs in the table above are recorded to other expense below income from operations in the Condensed Consolidated Statements of Income or capitalized as a regulatory asset. Approximately 40 percent of the costs are capitalized to regulatory assets and 60 percent is expensed to the income statement.

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AVISTA CORPORATION

 

NOTE 7. INCOME TAXES

In accordance with interim reporting requirements, the Company uses an estimated annual effective tax rate for computing its provisions for income taxes. An estimate of annual income tax expense (or benefit) is made each interim period using estimates for annual pre-tax income, income tax adjustments, and tax credits. The estimated annual effective tax rates do not include discrete events such as tax law changes, examination settlements, accounting method changes, or adjustments to tax expense or benefits attributable to prior years. Discrete events are recorded in the interim period in which they occur or become known. The estimated annual tax rate is applied to year-to-date pre-tax income to determine income tax expense (or benefit) for the interim period consistent with the annual estimate. In subsequent interim periods, income tax expense (or benefit) for the period is computed as the difference between the year-to-date amount reported for the previous interim period and the current period’s year-to-date amount.

The following table summarizes the significant factors impacting the difference between our effective tax rate and the federal statutory rate for the three and six months ended June 30 (dollars in thousands):

 

 

 

Three months ended June 30,

 

 

Six months ended June 30,

 

 

 

2020

 

 

2019

 

 

2020

 

 

2019

 

Federal income taxes at statutory

   rates

 

$

2,002

 

 

 

21.0

%

 

$

4,874

 

 

 

21.0

%

 

$

13,963

 

 

 

21.0

%

 

$

35,513

 

 

 

21.0

%

Increase (decrease) in tax resulting

   from:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Tax effect of regulatory

   treatment of utility plant

   differences

 

 

(2,415

)

 

 

(25.3

)

 

 

(2,139

)

 

 

(9.2

)

 

 

(4,817

)

 

 

(7.2

)

 

 

(4,219

)

 

 

(2.5

)

State income tax expense

 

 

(325

)

 

 

(3.4

)

 

 

(8

)

 

 

 

 

 

902

 

 

 

1.4

 

 

 

1,651

 

 

 

1.0

 

Acquisition costs

 

 

 

 

 

 

 

 

112

 

 

 

0.5

 

 

 

 

 

 

 

 

 

(1,712

)

 

 

(1.0

)

Non-plant excess deferred turnaround (1)

 

 

(8,390

)

 

 

(88.0

)

 

 

(5,091

)

 

 

(21.9

)

 

 

(8,476

)

 

 

(12.7

)

 

 

(5,601

)

 

 

(3.3

)

Tax loss on sale of METALfx

 

 

 

 

 

 

 

 

(1,259

)

 

 

(5.4

)

 

 

 

 

 

 

 

 

(1,259

)

 

 

(0.8

)

Valuation allowance

 

 

 

 

 

 

 

 

1,245

 

 

 

5.3

 

 

 

 

 

 

 

 

 

1,245

 

 

 

0.7

 

Settlement of equity awards

 

 

 

 

 

 

 

 

 

 

 

 

 

 

165

 

 

 

0.1

 

 

 

612

 

 

 

0.4

 

Other

 

 

1,209

 

 

 

12.7

 

 

 

525

 

 

 

2.2

 

 

 

(1,124

)

 

 

(1.7

)

 

 

2,046

 

 

 

1.2

 

Total income tax expense

 

$

(7,919

)

 

 

(83.0

)%

 

$

(1,741

)

 

 

(7.5

)%

 

$

613

 

 

 

0.9

%

 

$

28,276

 

 

 

16.7

%

(1)

In March 2020, the WUTC approved an all-party settlement agreement related to electric tax benefits that were set aside for Colstrip in the 2020 general rate case order. In the approved settlement agreement, the parties agreed to utilize approximately $10.9 million ($8.4 million when tax-effected) of the electric tax benefits to offset costs associated with accelerating the depreciation of Colstrip Units 3 & 4, to reflect a remaining useful life of those units through December 31, 2025. In the second quarter 2020, the Company recorded a one-time increase to depreciation expense with an offsetting decrease to income tax expense.

 

In March 2019, the IPUC approved an all-party settlement agreement related to electric tax benefits that were set aside for Colstrip in the 2020 general rate case order. In the approved settlement agreement, the parties agreed to utilize approximately $6.4 million ($5.1 million when tax-effected) of the electric tax benefits to offset costs associated with accelerating the depreciation of Colstrip Units 3 & 4, to reflect a remaining useful life of those units through December 31, 2027. In the second quarter 2019, the Company recorded a one-time increase to depreciation expense with an offsetting decrease to income tax expense.

 

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NOTE 8. COMMITTED LINES OF CREDIT

Avista Corp.

Avista Corp. has a committed line of credit with various financial institutions in the total amount of $400.0 million. During the second quarter, the Company amended and extended, for one additional year, the revolving line of credit agreement for a revised expiration date of April 2022, with the option to extend for an additional one year period. The committed line of credit is secured by non-transferable first mortgage bonds of the Company issued to the agent bank that would only become due and payable in the event, and then only to the extent, that the Company defaults on its obligations under the committed line of credit.

Balances outstanding and interest rates of borrowings (excluding letters of credit) under the Company’s revolving committed line of credit were as follows as of June 30, 2020 and December 31, 2019 (dollars in thousands):

 

 

 

June 30,

 

 

December 31,

 

 

 

2020

 

 

2019

 

Balance outstanding at end of period

 

$

221,000

 

 

$

182,300

 

Letters of credit outstanding at end of period

 

$

19,373

 

 

$

21,473

 

Average interest rate at end of period

 

 

1.22

%

 

 

2.64

%

 

As of June 30, 2020 and December 31, 2019, the borrowings outstanding under Avista Corp.'s committed line of credit were classified as short-term borrowings on the Condensed Consolidated Balance Sheet.

AEL&P

AEL&P has a committed line of credit in the amount of $25.0 million that expires in November 2024. As of June 30, 2020 and December 31, 2019, there were borrowings of $0 and $3.5 million, respectively, and there were 0 letters of credit outstanding under this committed line of credit. The committed line of credit is secured by non-transferable first mortgage bonds of AEL&P issued to the agent bank that would only become due and payable in the event, and then only to the extent, that AEL&P defaults on its obligations under the committed line of credit.

NOTE 9. CREDIT AGREEMENT

Credit Agreement

On April 6, 2020, the Company entered into a Credit Agreement with U.S. Bank National Association, as Lender and Administrative Agent, and CoBank, ACB, as Lender, in the amount of $100 million at an interest rate of 1-Month LIBOR plus 125 basis points with an expiration date of April 5, 2021. Indebtedness under this agreement is unsecured.

The Credit Agreement contains customary covenants and default provisions, including a covenant not to permit the ratio of "consolidated total debt" to "consolidated total capitalization" of Avista Corp. to be greater than 65 percent at any time.

The Company has borrowed the entire $100 million available under this agreement, which is being used to provide additional liquidity. The borrowing can be prepaid; however, the amount prepaid cannot be re-borrowed.

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NOTE 10. LONG-TERM DEBT TO AFFILIATED TRUSTS

In 1997, the Company issued Floating Rate Junior Subordinated Deferrable Interest Debentures, Series B, with a principal amount of $51.5 million to Avista Capital II, an affiliated business trust formed by the Company. Avista Capital II issued $50.0 million of Preferred Trust Securities with a floating distribution rate of LIBOR plus 0.875 percent, calculated and reset quarterly.

The distribution rates paid were as follows during the six months ended June 30, 2020 and the year ended December 31, 2019:

 

 

 

June 30,

 

 

December 31,

 

 

 

2020

 

 

2019

 

Low distribution rate

 

 

1.23

%

 

 

2.79

%

High distribution rate

 

 

2.79

%

 

 

3.61

%

Distribution rate at the end of the period

 

 

1.23

%

 

 

2.79

%

 

Concurrent with the issuance of the Preferred Trust Securities, Avista Capital II issued $1.5 million of Common Trust Securities to the Company. The Preferred Trust Securities may be redeemed at the option of Avista Capital II at any time and mature on June 1, 2037. In December 2000, the Company purchased $10.0 million of these Preferred Trust Securities.

The Company owns 100 percent of Avista Capital II and has solely and unconditionally guaranteed the payment of distributions on, and redemption price and liquidation amount for, the Preferred Trust Securities to the extent that Avista Capital II has funds available for such payments from the respective debt securities. Upon maturity or prior redemption of such debt securities, the Preferred Trust Securities will be mandatorily redeemed. The Company does not include these capital trusts in its consolidated financial statements as Avista Corp. is not the primary beneficiary. As such, the sole assets of the capital trusts are $51.5 million of junior subordinated deferrable interest debentures of Avista Corp., which are reflected on the Condensed Consolidated Balance Sheets. Interest expense to affiliated trusts in the Condensed Consolidated Statements of Income represents interest expense on these debentures.

NOTE 11. FAIR VALUE

The carrying values of cash and cash equivalents, accounts and notes receivable, accounts payable, and short-term borrowings are reasonable estimates of their fair values. Long-term debt (including current portion and material capital leases) and long-term debt to affiliated trusts are reported at carrying value on the Condensed Consolidated Balance Sheets.

The fair value hierarchy prioritizes the inputs used to measure fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1 measurement) and the lowest priority to fair values derived from unobservable inputs (Level 3 measurement).

The three levels of the fair value hierarchy are defined as follows:

Level 1 – Quoted prices are available in active markets for identical assets or liabilities. Active markets are those in which transactions for the asset or liability occur with sufficient frequency and volume to provide pricing information on an ongoing basis.

Level 2 – Pricing inputs are other than quoted prices in active markets included in Level 1, but which are either directly or indirectly observable as of the reporting date. Level 2 includes those financial instruments that are valued using models or other valuation methodologies. These models are primarily industry-standard models that consider various assumptions, including quoted forward prices for commodities, time value, volatility factors, and current market and contractual prices for the underlying instruments, as well as other relevant economic measures. Substantially all of these assumptions are observable in the marketplace throughout the full term of the instrument, can be derived from observable data or are supported by observable levels at which transactions are executed in the marketplace.

Level 3 – Pricing inputs include significant inputs that are generally unobservable from objective sources. These inputs may be used with internally developed methodologies that result in management’s best estimate of fair value.

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Financial assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement. The Company’s assessment of the significance of a particular input to the fair value measurement requires judgment, and may affect the valuation of fair value assets and liabilities and their placement within the fair value hierarchy levels. The determination of the fair values incorporates various factors that not only include the credit standing of the counterparties involved and the impact of credit enhancements (such as cash deposits and letters of credit), but also the impact of Avista Corp.’s nonperformance risk on its liabilities.

The following table sets forth the carrying value and estimated fair value of the Company’s financial instruments not reported at estimated fair value on the Condensed Consolidated Balance Sheets as of June 30, 2020 and December 31, 2019 (dollars in thousands):

 

 

 

June 30, 2020

 

 

December 31, 2019

 

 

 

Carrying

Value

 

 

Estimated

Fair Value

 

 

Carrying

Value

 

 

Estimated

Fair Value

 

Long-term debt (Level 2)

 

$

963,500

 

 

$

1,173,171

 

 

$

963,500

 

 

$

1,124,649

 

Long-term debt (Level 3)

 

 

947,000

 

 

 

1,097,318

 

 

 

947,000

 

 

 

1,048,440

 

Snettisham finance lease obligation (Level 3)

 

 

53,150

 

 

 

59,400

 

 

 

54,550

 

 

 

58,000

 

Long-term debt to affiliated trusts (Level 3)

 

 

51,547

 

 

 

36,083

 

 

 

51,547

 

 

 

41,238

 

 

These estimates of fair value of long-term debt and long-term debt to affiliated trusts were primarily based on available market information, which generally consists of estimated market prices from third party brokers for debt with similar risk and terms. The price ranges obtained from the third party brokers consisted of par values of 70.00 to 142.77, where a par value of 100.0 represents the carrying value recorded on the Condensed Consolidated Balance Sheets. Level 2 long-term debt represents publicly issued bonds with quoted market prices; however, due to their limited trading activity, they are classified as Level 2 because brokers must generate quotes and make estimates if there is no trading activity near a period end. Level 3 long-term debt consists of private placement bonds and debt to affiliated trusts, which typically have no secondary trading activity. Fair values in Level 3 are estimated based on market prices from third party brokers using secondary market quotes for debt with similar risk and terms to generate quotes for Avista Corp. bonds. Due to the unique nature of the Snettisham finance lease obligation, the estimated fair value of these items was determined based on a discounted cash flow model using available market information. The Snettisham finance lease obligation was discounted to present value using the Morgan Markets A Ex-Fin discount rate as published on June 30, 2020.

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The following table discloses by level within the fair value hierarchy the Company’s assets and liabilities measured and reported on the Condensed Consolidated Balance Sheets as of June 30, 2020 and December 31, 2019 at fair value on a recurring basis (dollars in thousands):

 

 

 

Level 1

 

 

Level 2

 

 

Level 3

 

 

Counterparty

and Cash

Collateral

Netting (1)

 

 

Total

 

June 30, 2020

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Assets:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Energy commodity derivatives

 

$

 

 

$

34,896

 

 

$

 

 

$

(33,952

)

 

$

944

 

Foreign currency exchange derivatives

 

 

 

 

 

7

 

 

 

 

 

 

(7

)

 

 

 

Deferred compensation assets:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Mutual Funds:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Fixed income securities (2)

 

 

2,559

 

 

 

 

 

 

 

 

 

 

 

 

2,559

 

Equity securities (2)

 

 

5,464

 

 

 

 

 

 

 

 

 

 

 

 

5,464

 

Total

 

$

8,023

 

 

$

34,903

 

 

$

 

 

$

(33,959

)

 

$

8,967

 

Liabilities:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Energy commodity derivatives

 

$

 

 

$

31,427

 

 

$

 

 

$

(30,983

)

 

$

444

 

Level 3 energy commodity derivatives:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Natural gas exchange agreement

 

 

 

 

 

 

 

 

2,628

 

 

 

 

 

 

2,628

 

Foreign currency exchange derivatives

 

 

 

 

 

25

 

 

 

 

 

 

(7

)

 

 

18

 

Interest rate swap derivatives

 

 

 

 

 

78,018

 

 

 

 

 

 

(10,980

)

 

 

67,038

 

Total

 

$

 

 

$

109,470

 

 

$

2,628

 

 

$

(41,970

)

 

$

70,128

 

December 31, 2019

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Assets:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Energy commodity derivatives

 

$

 

 

$

41,546

 

 

$

 

 

$

(40,452

)

 

$

1,094

 

Level 3 energy commodity derivatives:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Natural gas exchange agreement

 

 

 

 

 

 

 

 

27

 

 

 

(27

)

 

 

 

Foreign currency exchange derivatives

 

 

 

 

 

97

 

 

 

 

 

 

 

 

 

97

 

Interest rate swap derivatives

 

 

 

 

 

1,552

 

 

 

 

 

 

(963

)

 

 

589

 

Deferred compensation assets:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Mutual Funds:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Fixed income securities (2)

 

 

2,232

 

 

 

 

 

 

 

 

 

 

 

 

2,232

 

Equity securities (2)

 

 

6,271

 

 

 

 

 

 

 

 

 

 

 

 

6,271

 

Total

 

$

8,503

 

 

$

43,195

 

 

$

27

 

 

$

(41,442

)

 

$

10,283

 

Liabilities:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Energy commodity derivatives

 

$

 

 

$

45,144

 

 

$

 

 

$

(43,830

)

 

$

1,314

 

Level 3 energy commodity derivatives:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Natural gas exchange agreement

 

 

 

 

 

 

 

 

3,003

 

 

 

(27

)

 

 

2,976

 

Interest rate swap derivatives

 

 

 

 

 

34,056

 

 

 

 

 

 

(7,733

)

 

 

26,323

 

Total

 

$

 

 

$

79,200

 

 

$

3,003

 

 

$

(51,590

)

 

$

30,613

 

 

(1)

The Company is permitted to net derivative assets and derivative liabilities with the same counterparty when a legally enforceable master netting agreement exists. In addition, the Company nets derivative assets and derivative liabilities against any payables and receivables for cash collateral held or placed with these same counterparties.

(2)

These assets are included in other property and investments-net and other non-current assets on the Condensed Consolidated Balance Sheets.

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The difference between the amount of derivative assets and liabilities disclosed in respective levels in the table above and the amount of derivative assets and liabilities disclosed on the Condensed Consolidated Balance Sheets is due to netting arrangements with certain counterparties. See Note 5 for additional discussion of derivative netting.

To establish fair value for energy commodity derivatives, the Company uses quoted market prices and forward price curves to estimate the fair value of energy commodity derivative instruments included in Level 2. In particular, electric derivative valuations are performed using market quotes, adjusted for periods in between quotable periods. Natural gas derivative valuations are estimated using New York Mercantile Exchange pricing for similar instruments, adjusted for basin differences, using market quotes. Where observable inputs are available for substantially the full term of the contract, the derivative asset or liability is included in Level 2.

To establish fair values for interest rate swap derivatives, the Company uses forward market curves for interest rates for the term of the swaps and discounts the cash flows back to present value using an appropriate discount rate. The discount rate is calculated by third party brokers according to the terms of the swap derivatives and evaluated by the Company for reasonableness, with consideration given to the potential non-performance risk by the Company. Future cash flows of the interest rate swap derivatives are equal to the fixed interest rate in the swap compared to the floating market interest rate multiplied by the notional amount for each period.

To establish fair value for foreign currency derivatives, the Company uses forward market curves for Canadian dollars against the US dollar and multiplies the difference between the locked-in price and the market price by the notional amount of the derivative. Forward foreign currency market curves are provided by third party brokers. The Company's credit spread is factored into the locked-in price of the foreign exchange contracts.

Deferred compensation assets and liabilities represent funds held by the Company in a Rabbi Trust for an executive deferral plan. These funds consist of actively traded equity and bond funds with quoted prices in active markets. The balance disclosed in the table above excludes cash and cash equivalents of $0.4 million as of June 30, 2020 and December 31, 2019.

Level 3 Fair Value

The following table presents the quantitative information which was used to estimate the fair values of the Level 3 assets and liabilities above as of June 30, 2020 (dollars in thousands):

 

 

 

Fair Value

(Net) at

 

 

Valuation

 

Unobservable

 

Range and Weighted

 

 

June 30, 2020

 

 

Technique

 

Input

 

Average Price

Natural gas exchange agreement

 

$

(2,628

)

 

Internally derived weighted average cost of gas

 

Forward purchase prices

 

$1.55/mmBTU

$1.55 Weighted Average

 

 

 

 

 

 

 

 

Forward sales prices

 

$1.85 - $3.88/mmBTU

$3.27 Weighted Average

 

 

 

 

 

 

 

 

Purchase volumes

 

75,000 mmBTUs

 

 

 

 

 

 

 

 

Sales volumes

 

140,000 - 310,000 mmBTUs

 

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The following table presents activity for energy commodity derivative assets (liabilities) measured at fair value using significant unobservable inputs (Level 3) for the six months ended June 30 (dollars in thousands):

 

 

 

Natural Gas

Exchange

Agreement

 

 

Power

Exchange

Agreement

 

 

Total

 

Three months ended June 30, 2020:

 

 

 

 

 

 

 

 

 

 

 

 

Balance as of April 1, 2020

 

$

(2,253

)

 

$

 

 

$

(2,253

)

Total gains or (losses) (realized/unrealized):

 

 

 

 

 

 

 

 

 

 

 

 

Included in regulatory assets/liabilities (1)

 

 

(391

)

 

 

 

 

 

(391

)

Settlements

 

 

16

 

 

 

 

 

 

16

 

Ending balance as of June 30, 2020 (2)

 

$

(2,628

)

 

$

 

 

$

(2,628

)

Three months ended June 30, 2019:

 

 

 

 

 

 

 

 

 

 

 

 

Balance as of April 1, 2019

 

$

(2,104

)

 

$

(612

)

 

$

(2,716

)

Total gains or (losses) (realized/unrealized):

 

 

 

 

 

 

 

 

 

 

 

 

Included in regulatory assets/liabilities (1)

 

 

(829

)

 

 

1,454

 

 

 

625

 

Settlements

 

 

(59

)

 

 

(842

)

 

 

(901

)

Ending balance as of June 30, 2019 (2)

 

$

(2,992

)

 

$

 

 

$

(2,992

)

Six months ended June 30, 2020:

 

 

 

 

 

 

 

 

 

 

 

 

Balance as of January 1, 2020

 

$

(2,976

)

 

$

 

 

$

(2,976

)

Total gains or (losses) (realized/unrealized):

 

 

 

 

 

 

 

 

 

 

 

 

Included in regulatory assets/liabilities (1)

 

 

94

 

 

 

 

 

 

94

 

Settlements

 

 

254

 

 

 

 

 

 

254

 

Ending balance as of June 30, 2020 (2)

 

$

(2,628

)

 

$

 

 

$

(2,628

)

Six months ended June 30, 2019:

 

 

 

 

 

 

 

 

 

 

 

 

Balance as of January 1, 2019

 

$

(2,774

)

 

$

(2,488

)

 

$

(5,262

)

Total gains or (losses) (realized/unrealized):

 

 

 

 

 

 

 

 

 

 

 

 

Included in regulatory assets/liabilities (1)

 

 

8,148

 

 

436

 

 

 

8,584

 

Settlements

 

 

(8,366

)

 

 

2,052

 

 

 

(6,314

)

Ending balance as of June 30, 2019 (2)

 

$

(2,992

)

 

$

 

 

$

(2,992

)

 

(1)

All gains and losses are included in other regulatory assets and liabilities. There were no gains and losses included in either net income or other comprehensive income during any of the periods presented in the table above.

(2)

There were no purchases, issuances or transfers from other categories of any derivatives instruments during the periods presented in the table above.

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NOTE 12. COMMON STOCK

During the second quarter of 2020, the Company entered into 4 separate sales agency agreements under which the sales agents may offer and sell new shares of the Company’s common stock from time to time. The Company issued 0.6 million shares during the three and six months ended June 30, 2020, under the new sales agency agreements. These agreements provide for the offering of a maximum of approximately 3.2 million shares, of which approximately 2.6 million remain unissued as of June 30, 2020. Prior to the new agreements, the Company was party to four separate sales agency agreements that expired on February 29, 2020. The Company did 0t issue any shares under the expired agreements in 2020.

NOTE 13. ACCUMULATED OTHER COMPREHENSIVE LOSS

Accumulated other comprehensive loss, net of tax, consisted of the following as of June 30, 2020 and December 31, 2019 (dollars in thousands):

 

 

 

June 30,

2020

 

 

December 31,

2019

 

Unfunded benefit obligation for pensions and other postretirement benefit plans -

   net of taxes of $2,614 and $2,727, respectively

 

$

9,834

 

 

$

10,259

 

 

The following table details the reclassifications out of accumulated other comprehensive loss to net income by component for the three and six months ended June 30 (dollars in thousands).

 

 

 

Amounts Reclassified from Accumulated Other

Comprehensive Loss

 

 

 

 

 

Three months ended June 30,

 

 

Six months ended June 30,

 

 

 

Details about Accumulated Other Comprehensive Loss Components

 

2020

 

 

2019

 

 

2020

 

 

2019

 

 

Affected Line Item in

Statement of Income

Amortization of defined benefit pension items

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Amortization of net prior service cost

 

$

(200

)

 

$

(200

)

 

$

(400

)

 

$

(400

)

 

(a)

Amortization of net loss

 

 

3,121

 

 

 

3,755

 

 

 

6,221

 

 

 

7,416

 

 

(a)

Adjustment due to effects of regulation

 

 

(2,642

)

 

 

(3,352

)

 

 

(5,283

)

 

 

(6,610

)

 

(a)

 

 

 

279

 

 

 

203

 

 

 

538

 

 

 

406

 

 

Total before tax

 

 

 

(59

)

 

 

(42

)

 

 

(113

)

 

 

(85

)

 

Tax expense

 

 

$

220

 

 

$

161

 

 

$

425

 

 

$

321

 

 

Net of tax

 

(a)

These accumulated other comprehensive loss components are included in the computation of net periodic pension cost (see Note 6 for additional details).

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NOTE 14. EARNINGS PER COMMON SHARE ATTRIBUTABLE TO AVISTA CORP. SHAREHOLDERS

The following table presents the computation of basic and diluted earnings per common share attributable to Avista Corp. shareholders for the three and six months ended June 30 (in thousands, except per share amounts):

 

 

 

Three months ended June 30,

 

 

Six months ended June 30,

 

 

 

2020

 

 

2019

 

 

2020

 

 

2019

 

Numerator:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Net income attributable to Avista Corp. shareholders

 

$

17,453

 

 

$

25,319

 

 

$

65,877

 

 

$

141,113

 

Denominator:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Weighted-average number of common shares

   outstanding-basic

 

 

67,481

 

 

 

65,894

 

 

 

67,360

 

 

 

65,814

 

Effect of dilutive securities:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Performance and restricted stock awards

 

 

108

 

 

 

69

 

 

 

125

 

 

 

69

 

Weighted-average number of common shares

   outstanding-diluted

 

 

67,589

 

 

 

65,963

 

 

 

67,485

 

 

 

65,883

 

Earnings per common share attributable to Avista

   Corp. shareholders:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Basic

 

$

0.26

 

 

$

0.38

 

 

$

0.98

 

 

$

2.14

 

Diluted

 

$

0.26

 

 

$

0.38

 

 

$

0.98

 

 

$

2.14

 

 

There were 0 shares excluded from the calculation because they were antidilutive.

NOTE 15. COMMITMENTS AND CONTINGENCIES

In the course of its business, the Company becomes involved in various claims, controversies, disputes and other contingent matters, including the items described in this Note. Some of these claims, controversies, disputes and other contingent matters involve litigation or other contested proceedings. For all such matters, the Company intends to vigorously protect and defend its interests and pursue its rights. However, no assurance can be given as to the ultimate outcome of any particular matter because litigation and other contested proceedings are inherently subject to numerous uncertainties. For matters that affect Avista Utilities’ or AEL&P's operations, the Company intends to seek, to the extent appropriate, recovery of incurred costs through the ratemaking process.

2015 Washington General Rate Cases

In January 2016, the Company received an order (Order 05) that concluded its electric and natural gas general rate cases that were originally filed with the WUTC in February 2015. New electric and natural gas rates were effective on January 11, 2016.

PC Petition for Judicial Review

In March 2016, Public Counsel (PC) filed in Thurston County Superior Court a Petition for Judicial Review of the WUTC's Order 05 and Order 06. In April 2016, this matter was certified for review directly by the Court of Appeals, an intermediate appellate court in the State of Washington.

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On August 7, 2018, the Court of Appeals issued a "Published Opinion" (Opinion) which concluded that the WUTC's use of an attrition allowance to calculate Avista Corp.'s rate base violated Washington law. In the Opinion, the Court stated that because the projected additions to rate base in the future were not "used and useful" for service at the time the request for the rate increase was made, they may not lawfully be included in the Company's rate base to justify a rate increase. Accordingly, the Court concluded that the WUTC erred in including an attrition allowance in the calculation of Avista Corp.’s electric and natural gas rate base. The Court noted, however, that the law does not prohibit an attrition allowance in the calculation, for ratemaking purposes, of recoverable operating and maintenance expense. Since the WUTC order provided one lump sum attrition allowance without distinguishing what portion was for rate base and which was for operating and maintenance expenses or other considerations, the Court struck all portions of the attrition allowance attributable to Avista Corp.'s rate base and reversed and remanded the case for the WUTC to recalculate Avista Corp.’s rates without including an attrition allowance in the calculation of rate base.

On March 6, 2020, the Company received an order from the WUTC that will require it to refund $8.5 million to electric and natural gas customers. The Company will refund $4.9 million to electric customers and $3.6 million to natural gas customers. The Company previously recorded a customer refund liability of $3.6 million in 2019.

Boyds Fire (State of Washington Department of Natural Resources v. Avista)

On August 19, 2019, the Company was served with a complaint, captioned “State of Washington Department of Natural Resources v. Avista Corporation,” seeking recovery up to $4.4 million for fire suppression and investigation costs and related expenses incurred in connection with a wildfire that occurred in Ferry County, Washington in August 2018.  Specifically, the complaint alleges that the fire, which became known as the “Boyds Fire,” was caused by a dead ponderosa pine tree falling into an overhead distribution line, and that Avista Corp. was negligent in failing to identify and remove the tree before it came into contact with the line.  Avista Corp. disputes that the tree in question was the cause of the fire and that it was negligent in failing to identify and remove it. 

 

Two additional lawsuits have also been filed in connection with the Boyds Fire.  The first, captioned “Cox et al. v. Avista Corporation,” was filed on behalf of seven private landowners who seek recovery of property damages related to the fire.  The second, captioned “Liberty Insurance Corporation et al. v. Avista Corporation,” was filed on behalf of three insurance companies, which seek recovery of their subrogated interest in property damages alleged to have been incurred by four landowners in connection with the fire. 

 

All three suits were filed in the Superior Court of Ferry County, Washington. The Company intends to vigorously defend itself in the litigation.  However, the Company cannot predict the outcome of this matter. 

Other Contingencies

In the normal course of business, the Company has various other legal claims and contingent matters outstanding. The Company believes that any ultimate liability arising from these actions will not have a material impact on its financial condition, results of operations or cash flows. It is possible that a change could occur in the Company’s estimates of the probability or amount of a liability being incurred. Such a change, should it occur, could be significant. See "Note 21 of the Notes to Consolidated Financial Statements" in the 2019 Form 10-K for additional discussion regarding other contingencies.

NOTE 16. INFORMATION BY BUSINESS SEGMENTS

The business segment presentation reflects the basis used by the Company's management to analyze performance and determine the allocation of resources. The Company's management evaluates performance based on income (loss) from operations before income taxes as well as net income (loss) attributable to Avista Corp. shareholders. The accounting policies of the segments are the same as those described in the summary of significant accounting policies. Avista Utilities' business is managed based on the total regulated utility operation; therefore, it is considered one segment. AEL&P is a separate reportable business segment, as it has separate financial reports that are reviewed in detail by the Chief Operating Decision Maker and its operations and risks are sufficiently different from Avista Utilities and the other businesses at AERC that it cannot be aggregated with any other operating segments. The Other category, which is not a reportable segment, includes other investments and operations of various subsidiaries, as well as certain other operations of Avista Capital.

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The following table presents information for each of the Company’s business segments (dollars in thousands):

 

 

 

Avista

Utilities

 

 

Alaska

Electric

Light and

Power

Company

 

 

Total Utility

 

 

Other

 

 

Intersegment

Eliminations

(1)

 

 

Total

 

For the three months ended June 30, 2020:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Operating revenues

 

$

268,340

 

 

$

9,997

 

 

$

278,337

 

 

$

255

 

 

$

 

 

$

278,592

 

Resource costs

 

 

67,069

 

 

 

896

 

 

 

67,965

 

 

 

 

 

 

 

 

 

67,965

 

Other operating expenses

 

 

83,140

 

 

 

3,064

 

 

 

86,204

 

 

 

659

 

 

 

 

 

 

86,863

 

Depreciation and amortization

 

 

61,462

 

 

 

2,446

 

 

 

63,908

 

 

 

188

 

 

 

 

 

 

64,096

 

Income (loss) from operations

 

 

32,217

 

 

 

3,302

 

 

 

35,519

 

 

 

(593

)

 

 

 

 

 

34,926

 

Interest expense (2)

 

 

24,188

 

 

 

1,561

 

 

 

25,749

 

 

 

130

 

 

 

(47

)

 

 

25,832

 

Income taxes

 

 

(8,004

)

 

 

480

 

 

 

(7,524

)

 

 

(395

)

 

 

 

 

 

(7,919

)

Net income (loss) attributable to Avista

   Corp. shareholders

 

 

17,605

 

 

 

1,328

 

 

 

18,933

 

 

 

(1,480

)

 

 

 

 

 

17,453

 

Capital expenditures (3)

 

 

91,867

 

 

 

2,087

 

 

 

93,954

 

 

 

477

 

 

 

 

 

 

94,431

 

For the three months ended June 30, 2019:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Operating revenues

 

$

289,808

 

 

$

8,743

 

 

$

298,551

 

 

$

2,261

 

 

$

 

 

$

300,812

 

Resource costs

 

 

88,506

 

 

 

(67

)

 

 

88,439

 

 

 

 

 

 

 

 

 

88,439

 

Other operating expenses (4)

 

 

84,602

 

 

 

3,129

 

 

 

87,731

 

 

 

6,332

 

 

 

 

 

 

94,063

 

Depreciation and amortization

 

 

53,070

 

 

 

2,409

 

 

 

55,479

 

 

 

155

 

 

 

 

 

 

55,634

 

Income (loss) from operations

 

 

40,978

 

 

 

3,016

 

 

 

43,994

 

 

 

(4,226

)

 

 

 

 

 

39,768

 

Interest expense (2)

 

 

24,316

 

 

 

1,595

 

 

 

25,911

 

 

 

148

 

 

 

(197

)

 

 

25,862

 

Income taxes

 

 

(2,947

)

 

 

380

 

 

 

(2,567

)

 

 

826

 

 

 

 

 

 

(1,741

)

Net income attributable to Avista Corp. shareholders

 

 

21,219

 

 

 

1,076

 

 

 

22,295

 

 

 

3,024

 

 

 

 

 

 

25,319

 

Capital expenditures (3)

 

 

103,297

 

 

 

3,076

 

 

 

106,373

 

 

 

22

 

 

 

 

 

 

106,395

 

For the six months ended June 30, 2020:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Operating revenues

 

$

645,545

 

 

$

22,199

 

 

$

667,744

 

 

$

1,078

 

 

$

 

 

$

668,822

 

Resource costs

 

 

196,625

 

 

887

 

 

 

197,512

 

 

 

 

 

 

 

 

 

197,512

 

Other operating expenses

 

 

174,420

 

 

 

6,280

 

 

 

180,700

 

 

 

2,019

 

 

 

 

 

 

182,719

 

Depreciation and amortization

 

 

110,436

 

 

 

4,893

 

 

 

115,329

 

 

 

423

 

 

 

 

 

 

115,752

 

Income (loss) from operations

 

 

108,935

 

 

 

9,548

 

 

 

118,483

 

 

 

(1,364

)

 

 

 

 

 

117,119

 

Interest expense (2)

 

 

49,171

 

 

 

3,149

 

 

 

52,320

 

 

 

262

 

 

 

(132

)

 

 

52,450

 

Income taxes

 

 

(600

)

 

 

1,781

 

 

 

1,181

 

 

 

(568

)

 

 

 

 

 

613

 

Net income attributable to Avista

   Corp. shareholders

 

 

63,584

 

 

 

4,723

 

 

 

68,307

 

 

 

(2,430

)

 

 

 

 

 

65,877

 

Capital expenditures (3)

 

 

185,923

 

 

 

3,557

 

 

 

189,480

 

 

 

586

 

 

 

 

 

 

190,066

 

For the six months ended June 30, 2019:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Operating revenues

 

$

667,510

 

 

$

19,624

 

 

$

687,134

 

 

$

10,159

 

 

$

 

 

$

697,293

 

Resource costs

 

 

227,218

 

 

 

(1,432

)

 

 

225,786

 

 

 

 

 

 

 

 

 

225,786

 

Other operating expenses (4)

 

 

185,185

 

 

 

6,188

 

 

 

191,373

 

 

 

13,687

 

 

 

 

 

 

205,060

 

Depreciation and amortization

 

 

99,577

 

 

 

4,816

 

 

 

104,393

 

 

 

364

 

 

 

 

 

 

104,757

 

Income (loss) from operations

 

 

101,202

 

 

 

9,529

 

 

 

110,731

 

 

 

(3,892

)

 

 

 

 

 

106,839

 

Interest expense (2)

 

 

48,580

 

 

 

3,191

 

 

 

51,771

 

 

 

736

 

 

 

(637

)

 

 

51,870

 

Income taxes

 

 

25,597

 

 

 

1,743

 

 

 

27,340

 

 

 

936

 

 

 

 

 

 

28,276

 

Net income (loss) attributable to Avista

   Corp. shareholders

 

 

133,120

 

 

 

4,628

 

 

 

137,748

 

 

 

3,365

 

 

 

 

 

 

141,113

 

Capital expenditures (3)

 

 

195,606

 

 

 

4,382

 

 

 

199,988

 

 

 

184

 

 

 

 

 

 

200,172

 

Total Assets:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

As of June 30, 2020:

 

$

5,932,490

 

 

$

273,314

 

 

$

6,205,804

 

 

$

111,591

 

 

$

(14,771

)

 

$

6,302,624

 

As of December 31, 2019:

 

$

5,713,268

 

 

$

271,393

 

 

$

5,984,661

 

 

$

113,390

 

 

$

(15,595

)

 

$

6,082,456

 

 

(1)

Intersegment eliminations reported as interest expense represent intercompany interest.

(2)

Including interest expense to affiliated trusts.

(3)

The capital expenditures for the other businesses are included in other investing activities on the Condensed Consolidated Statements of Cash Flows.

(4)

Other operating expenses for Avista Utilities for the six months ended June 30, 2019 include merger transaction costs which are separately disclosed on the Condensed Consolidated Statements of Income.

 

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NOTE 17. TERMINATION OF PROPOSED ACQUISITION BY HYDRO ONE

On July 19, 2017, Avista Corp. entered into a Merger Agreement that provided for Avista Corp. to become an indirect, wholly-owned subsidiary of Hydro One, subject to the satisfaction or waiver of specified closing conditions, including approval by regulatory agencies. Hydro One, based in Toronto, is Ontario’s largest electricity transmission and distribution provider.

Termination of the Merger Agreement

Due to the denial of the proposed merger by certain of the Company's regulatory commissions, on January 23, 2019, Avista Corp., Hydro One and certain subsidiaries thereof, entered into a Termination Agreement indicating their mutual agreement to terminate the Merger Agreement, effective immediately. Pursuant to the terms of the Termination Agreement, Hydro One paid Avista Corp. a $103 million termination fee on January 24, 2019. The termination fee was used for reimbursing the Company's transaction costs incurred from 2017 to 2019. The balance of the termination fee remaining after payment of 2019 transaction costs and applicable income taxes was used for general corporate purposes and reduced the Company's need for external financing. The 2019 costs totaled $19.7 million pre-tax and included financial advisers' fees, legal fees, consulting fees and employee time.

NOTE 18. SALE OF METALfx

In April 2019, Bay Area Manufacturing, Inc., a non-regulated subsidiary of Avista Corp., entered into a definitive agreement to sell its interest in METALfx to an independent third party. The transaction was a stock sale for a total cash purchase price of $17.5 million plus cash on-hand, subject to customary closing adjustments. The transaction closed on April 18, 2019, and as of that date the Company has no further involvement with METALfx.

The purchase price of $17.5 million, as adjusted, was divided among the security holders of METALfx, including the minority shareholder, pro rata based on ownership (Avista Corp. owned 89.2 percent of the equity of METALfx). As required under the purchase agreement, $1.2 million (7 percent of the purchase price) will be held in escrow for 24 months from the closing of the transaction to satisfy certain indemnification obligations.

When all escrow amounts are released, the sale transaction will provide cash proceeds to Avista Corp., net of payments to the minority holder, contractually obligated compensation payments and other transaction expenses, of $16.5 million and result in a net gain of $2.3 million recognized in the six months ended June 30, 2019. The Company expects to receive the full amount of its portion of the escrow accounts; therefore, the full amounts have been included in the gain calculation. The gross gain is included in "Other income," the transaction expenses paid are included in "Non-utility Other operating expenses" and any taxes associated with the sale are included in "Income tax expense" on the Condensed Consolidated Statements of Income.

Prior to the completion of the sales transaction, METALfx was not a reportable business segment and was included in other in the business segment footnote at Note 16. This transaction does not meet the criteria for discontinued operations as it does not represent a strategic shift that will have a major effect on the Company's ongoing operations.

 

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REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Shareholders and Board of Directors of

Avista Corporation

Spokane, Washington

Results of Review of Interim Financial Information

We have reviewed the accompanying condensed consolidated balance sheet of Avista Corporation and subsidiaries (the "Company") as of June 30, 2020, the related condensed consolidated statements of income, comprehensive income and equity, for the three-month and six-month periods ended June 30, 2020 and 2019 and of cash flows for the six-month periods ended June 30, 2020 and 2019 and the related notes (collectively referred to as the "interim financial information"). Based on our reviews, we are not aware of any material modifications that should be made to the accompanying interim financial information for it 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) (PCAOB), the consolidated balance sheet of the Company as of December 31, 2019, and the related consolidated statements of income, comprehensive income, equity, and cash flows for the year then ended (not presented herein); and in our report dated February 25, 2020, we expressed an unqualified opinion on those consolidated financial statements. In our opinion, the information set forth in the accompanying condensed consolidated balance sheet as of December 31, 2019, is fairly stated, in all material respects, in relation to the consolidated balance sheet from which it has been derived.

Basis for Review Results

This interim financial information is the responsibility of the Company's management. We are a public accounting firm registered with the PCAOB and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.

We conducted our reviews in accordance with standards of the PCAOB. 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 PCAOB, 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.

/s/ Deloitte & Touche LLP

Portland, Oregon

August 4, 2020

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

Management’s Discussion and Analysis of Financial Condition and Results of Operations has been prepared in accordance with GAAP for interim financial information and with the instructions to Form 10-Q. The interim Management’s Discussion and Analysis of Financial Condition and Results of Operations does not contain the full detail or analysis which would be included in a full fiscal year Form 10-K; therefore, it should be read in conjunction with the Company's 2019 Form 10-K.

Business Segments

Our business segments have not changed during the six months ended June 30, 2020. See the 2019 Form 10-K as well as “Note 16 of the Notes to Condensed Consolidated Financial Statements” for further information regarding our business segments.

The following table presents net income attributable to Avista Corp. shareholders for each of our business segments (and the other businesses) for the three and six months ended June 30 (dollars in thousands):

 

 

 

Three months ended June 30,

 

 

Six months ended June 30,

 

 

 

2020

 

 

2019

 

 

2020

 

 

2019

 

Avista Utilities

 

$

17,605

 

 

$

21,219

 

 

$

63,584

 

 

$

133,120

 

AEL&P

 

 

1,328

 

 

 

1,076

 

 

 

4,723

 

 

 

4,628

 

Other

 

 

(1,480

)

 

 

3,024

 

 

 

(2,430

)

 

 

3,365

 

Net income attributable to Avista Corp. shareholders

 

$

17,453

 

 

$

25,319

 

 

$

65,877

 

 

$

141,113

 

 

Executive Level Summary

Overall Results

Net income attributable to Avista Corp. shareholders was $17.5 million for the three months ended June 30, 2020, compared to $25.3 million for the three months ended June 30, 2019. Net income was $65.9 million for the six months ended June 30, 2020, compared to $141.1 million for the six months ended June 30, 2019.

Avista Utilities' net income for the three and six months ended June 30, 2020 decreased. For the second quarter, our earnings decreased due to lower utility margin from higher power supply costs and decreased loads from COVID-19, which was partially offset by rate relief in Washington and Oregon, and customer growth. In addition, we had lower operating expenses in the second quarter of 2020 compared to the second quarter of 2019. For the year-to-date, earnings decreased primarily due to the receipt, in the first quarter of 2019, of a $103 million termination fee from Hydro One (see "Note 17 of the Notes to Condensed Consolidated Financial Statements") which was partially offset by associated expenses of $19.7 million pre-tax. In addition, in the first half of 2020, we recorded an accrual for customer refunds related to the outcome of the 2015 Washington general rate cases outcome (see "Regulatory Matters"), an accrual for disallowed replacement power during an unplanned outage at Colstrip (see "Regulatory Matters"), and we had an increase in other operating expenses and depreciation and amortization, which were partially offset by a decrease in our income tax expense and resource costs.

AEL&P net income increased slightly, primarily due to higher sales volumes to residential and commercial customers in 2020 as a result of cooler than usual weather.

The decrease in net income at our other businesses for the year-to-date was primarily due to the sale of METALfx in 2019. In addition, we had impairment losses and accruals for bad debt in the first half of 2020, which was partially offset by investment gains associated with our equity investments.

More detailed explanations of the fluctuations are provided in the results of operations and business segment discussions (Avista Utilities, AEL&P, and the other businesses) that follow this section.

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COVID-19 Global Pandemic

The COVID-19 global pandemic is currently impacting all aspects of our business, as well as the global, national and local economies. It is likely that the continued spread of COVID-19 and efforts to contain the virus will continue to cause an economic slowdown and possibly a recession, resulting in significant disruptions in various public, commercial or industrial activities and causing employee absences which could interfere with operation and maintenance of the Company’s facilities. These circumstances have affected and will likely continue to adversely affect our operations, results of operations, financial condition and cash flows in the following ways:

Operations

We provide critical services to our customers. Accordingly, it is paramount that we keep our employees who operate our business safe so that we continue to provide reliable service. We implemented business continuity plans in the context of this global pandemic. We believe that we will continue to be able to conduct our utility operations effectively and provide safe and reliable service to our customers.

We have taken precautions concerning employee and facility hygiene, imposed travel limitations on employees and directed our employees to work remotely whenever possible. Protocols have been established and implemented to protect employees and the public when work requires public interaction. We have informed retail customers and state regulators that disconnections and late fees for non-payment are temporarily suspended.

During the second quarter of 2020, we began to experience supply chain delays due to the effects of the COVID-19 pandemic that have impacted the delivery times of some of our materials and equipment, with delays ranging from a couple weeks up to six weeks in some cases. At this time, the delays are being managed with minimal impact. The issues that could potentially result from future delays are being proactively mitigated through several planning and review activities, but could have an impact on our planned projects going forward.

Although we have not experienced any significant issues to date, it is possible that COVID-19 could have a negative impact on the ability of vendors or contractors to perform, which could increase operating costs and delay and/or increase the costs of capital projects.

Results of Operations

During the three months ended June 30, 2020, we experienced a material reduction in overall customer loads and retail revenues as the economic restrictions and closures continued in our service areas. In the three months ended June 30, 2020, when compared to normal, there was a decrease of approximately 6 percent on overall electric load, which consisted of approximately a 10 percent decrease in commercial and a 14 percent decrease in industrial, which was partially offset by an increase of 4 percent in residential. We expect a gradual economic recovery and prolonged high unemployment that will depress load and customer growth into 2021. We have decoupling and other regulatory mechanisms in Washington, Idaho and Oregon, which mitigate the impact of changes in loads and revenues for residential and certain commercial customer classes. There are limitations on increases in decoupling surcharges in a particular year and revenue recognition criteria established by GAAP. Although we expect to ultimately recognize all decoupling revenue, there can be a delay in revenue recognition. Over 90 percent of our utility revenue is covered by regulatory mechanisms.

We have suspended customer disconnections and late fees for non-payment; however in Idaho, the IPUC has approved resuming disconnections. Due to the economic downturn, our bad debt expense increased by $1.7 million in the second quarter and $3.3 million for the six months ended June 30, 2020 as compared to expectations. We expect bad debt expense to increase by $2.4 million for the remainder of 2020 as compared to our original forecast. In the second quarter of 2020, we deferred $1.1 million of the incremental bad debt expense.

We expect to offset at least some of the negative impacts of COVID-19 at Avista Utilities with cost savings and benefits from the Coronavirus Aid, Relief, and Economic Security Act (the CARES Act). We have filed petitions for an accounting order in each of our jurisdictions to defer the recognition of COVID-19 expenses as well as identified cost savings of other COVID-19 related benefits. See “Note 1 of Notes to Condensed Consolidated Financial Statements.”

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CARES Act

On March 27, 2020, the CARES Act, an economic stimulus package in response to COVID-19, was signed into law. The CARES Act contains corporate income tax provisions, including providing temporary changes regarding the prior and future utilization of net operating losses, temporary suspension of certain payment requirements for the employer portion of social security taxes, and the creation of certain refundable employee retention credits. We expect to be able to utilize $6.6 million ($7.9 million pre-tax) of benefits from the CARES Act to offset increased costs and lower utility margin associated with the COVID-19 pandemic. The benefits we expect to utilize are primarily derived from net operating loss carrybacks.

Financial Condition, Liquidity and Cash Flows

For 2020, we expect our net cash flows from operations to decrease primarily due to lower expected revenues from retail sales of electricity and natural gas and lower payments from customers.

We do not expect the impact of COVID-19 to change our estimate of utility capital expenditures for 2020. It is possible that a prolonged economic restrictions or business interruption could cause a decrease in our utility capital expenditures.

Disruptions and overall declines in the financial markets have decreased the fair value of pension plan assets and lower discount rates will increase the pension liability. This could ultimately increase future pension plan funding requirements and expenses. The impact on pension plan assets is mitigated as a significant portion of the assets are fixed-income securities with a target of 49 percent.

As of June 30, 2020, we had $159.6 million of available liquidity under the Avista Corp. $400.0 million committed line of credit and $25.0 million under the AEL&P committed line of credit. In addition, in April 2020, we entered into a one-year credit agreement with two financial institutions in the amount of $100.0 million. We borrowed the entire $100.0 million available under this agreement.

After considering the impacts of COVID-19, including the expectation of lower net operating cash flows, and the expected issuances of long-term debt and equity during 2020, we expect net cash flows from operations, together with cash available under our committed lines of credit and the $100.0 million borrowed under the new credit agreement, to provide adequate resources to fund capital expenditures, dividends, and other contractual commitments.

However, disruption, weakness and volatility in the financial markets could increase our costs, and delay our ability, to fund capital requirements from conventional sources. To the extent that access to the capital markets is adversely affected, we may need to consider alternative sources of funding for operations and for working capital, any of which could increase our cost of capital.

In addition to any of the issues identified above, we cannot predict the duration and severity of the COVID-19 global pandemic. The longer and more severe the economic restrictions and business disruption is, the greater the impact on our operations, results of operations, financial condition and cash flows will be.

Executive Order re Securing the United States Bulk Power System

On May 1, 2020, the President of the United States signed an Executive Order titled “Securing the United States Bulk-Power System.”  The executive order purports to limit the acquisition, importation, transfer or installation of bulk power system equipment sourced from foreign adversaries.  At this time, and pending future rulemaking, the full scope of the order is not yet known.  We are currently evaluating the potential impacts of the order, and will seek recovery of any associated costs through the ratemaking process.

Regulatory Matters

General Rate Cases

We regularly review the need for electric and natural gas rate changes in each state in which we provide service. We expect to continue to file for rate adjustments to:

 

seek recovery of operating costs and capital investments, and

 

seek the opportunity to earn reasonable returns as allowed by regulators.

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With regards to the timing and plans for future filings, the assessment of our need for rate relief and the development of rate case plans takes into consideration short-term and long-term needs, as well as specific factors that can affect the timing of rate filings. Such factors include, but are not limited to, in-service dates of major capital investments and the timing of changes in major revenue and expense items.

Avista Utilities

Washington General Rate Cases

2015 General Rate Cases

In January 2016, we received an order that concluded our electric and natural gas general rate cases that were originally filed with the WUTC in February 2015. New electric and natural gas rates were effective on January 11, 2016.

PC Petition for Judicial Review

In March 2016, PC filed in Thurston County Superior Court a Petition for Judicial Review of the WUTC's Orders. In April 2016, this matter was certified for review directly by the Court of Appeals, an intermediate appellate court in the State of Washington.

On August 7, 2018, the Court of Appeals issued a "Published Opinion" (Opinion) which concluded that the WUTC's use of an attrition allowance to calculate Avista Corp.'s rate base violated Washington law. In the Opinion, the Court stated that because the projected additions to rate base in the future were not "used and useful" for service at the time the request for the rate increase was made, they may not lawfully be included in our rate base to justify a rate increase. Accordingly, the Court concluded that the WUTC erred in including an attrition allowance in the calculation of our electric and natural gas rate base. The Court noted, however, that the law does not prohibit an attrition allowance in the calculation, for ratemaking purposes, of recoverable operating and maintenance expense. Since the WUTC order provided one lump sum attrition allowance without distinguishing what portion was for rate base and which was for operating and maintenance expenses or other considerations, the Court struck all portions of the attrition allowance attributable to our rate base and reversed and remanded the case for the WUTC to recalculate our rates without including an attrition allowance in the calculation of rate base.

On March 6, 2020, we received an order from the WUTC that requires us to refund $8.5 million to electric and natural gas customers. We will refund $4.9 million to electric customers and $3.6 million to natural gas customers. We previously recorded a customer refund liability of $3.6 million in 2019. The refund will be returned to customers over one year and began on April 1, 2020.

2019 General Rate Cases

On March 25, 2020, we received an order from the WUTC that approved the partial multi-party settlement agreement that was filed on November 21, 2019. The approved rates are designed to increase annual base electric revenues by $28.5 million, or 5.7 percent, and annual natural gas base revenues by $8.0 million, or 8.5 percent, effective April 1, 2020. The revenue increases are based on a 9.4 percent return on equity with a common equity ratio of 48.5 percent and a rate of return on rate base of 7.21 percent.

As part of the WUTC order, we will return approximately $40 million from the ERM rebate to customers over a two-year period. The ERM rebate includes approximately $3 million that was recently disallowed by the WUTC for the cost of replacement power during an unplanned outage at the Colstrip generating facility in 2018. The WUTC directed us to return a larger portion of the ERM money during the first year to achieve a net-zero billed impact to electric customers.

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Included in the WUTC order is the acceleration of depreciation of Colstrip Units 3 & 4 to reflect a remaining useful life through December 31, 2025. The order utilizes certain electric tax benefits associated with the 2018 tax reform to partially offset these increased costs. The order also sets aside $3 million for community transition efforts to mitigate the impacts of the eventual closure of Colstrip, half funded by customers and half funded by our shareholders. We recorded this liability and recognized the shareholder portion of the expense in the first quarter of 2020.

Lastly, the order includes the extension of electric and natural gas decoupling mechanisms through March 31, 2025, with one modification in that new customers added after any test period would not be decoupled until included in a future test period.

2020 General Rate Cases

We expect to file electric and natural gas general rate cases with the WUTC in the fourth quarter of 2020.

Idaho General Rate Cases

2019 General Rate Cases

On October 11, 2019, Avista Corp. and all parties to our electric general rate case reached a settlement agreement that was approved by the IPUC. New rates went into effect on December 1, 2019.

The rates that went into effect are designed to decrease annual base electric revenues by $7.2 million (or 2.8 percent), effective December 1, 2019. The settlement revenue decreases are based on a 9.5 percent ROE with a common equity ratio of 50 percent and a rate of return ROR on rate base of 7.35 percent, which is a continuation of current levels. This outcome is in line with our expectations.

The primary element of the difference in the agreed upon base revenues in the settlement agreement from our original request is that the settlement includes the continued recovery of costs for our wind generation power purchase agreements, which will include Palouse Wind and Rattlesnake Flat, through the PCA mechanism rather than through base rates.

2020 General Rate Cases

We expect to file electric and natural gas general rate cases with the IPUC in the fourth quarter of 2020.

Oregon General Rate Cases

2019 General Rate Case

On October 9, 2019, the OPUC approved the all-party settlement agreements filed in the third quarter of 2019. New rates went into effect on January 15, 2020.

OPUC approved rates that are designed to increase annual natural gas billed revenues by $3.6 million, or 4.2 percent.

The OPUC’s decision reflects a ROR on rate base of 7.24 percent, with a common equity ratio of 50 percent and a 9.4 percent ROE, both of which represent a continuation of existing authorized levels.

In addition, the approved settlement agreements included agreement among the parties to a future independent review of our interest rate hedging practices, with any recommendations based on the results and findings in the final report to be applicable only on a prospective basis and do not apply to any prior interest rate hedging activity.

2020 General Rate Case

On March 16, 2020, we filed a natural gas general rate case with the OPUC. We have requested an overall increase in base natural gas rates of 9.8 percent (designed to increase annual natural gas revenues by $6.8 million). Our request is based on a proposed ROR of 7.50 percent with a common equity ratio of 50 percent and a 9.9 percent ROE.

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On May 18, 2020, the Parties in the general rate case, including the OPUC Staff, reached a Partial Settlement Stipulation on Cost of Capital. The agreed-upon ROE is 9.4 percent, with a common equity ratio of 50 percent and a proposed ROR of 7.24 percent. This settlement reduces the overall revenue increase by $1.1 million.

Petition for Judicial Review of the Deferral of Capital Projects

In February 2019 and October 2018, the OPUC issued orders which concluded that, contrary to the OPUC's past practice, Oregon statutes that authorize the deferral of expense for later recovery from customers do not authorize the OPUC to allow deferrals of any costs related to capital investments (utility plant). In April 2019, Avista Corp. and other petitioners filed a Petition for Judicial Review with the Oregon Court of Appeals seeking review of the above OPUC orders. The OPUC, on April 6, 2020, rescinded its prior orders that were the subject of the appeal, and issued a proposed order meant to replace the orders on appeal. The affected utilities, including Avista Corp., advised the OPUC that they do not take exceptions to the proposed order, which reinstates the OPUC’s general authority to approve full revenue requirement deferrals, including a return of and on investment. The OPUC issued their official order on April 30, 2020.

AMI Project

In March 2016, the WUTC granted our Petition for an Accounting Order to defer and include in a regulatory asset the undepreciated value of our existing Washington electric meters for the opportunity for later recovery. This accounting treatment is related to our plans to replace our existing electric meters with new two-way digital meters and the related software and support services through our AMI project in Washington State. As of June 30, 2020, the estimated future undepreciated value for the existing electric meters was $22.2 million. In September 2017, the WUTC also approved our request to defer the undepreciated net book value of existing natural gas encoder receiver transmitters (ERT) (consistent with the accounting treatment we obtained on our existing electric meters) that will be retired as part of the AMI project. As of June 30, 2020, the estimated future undepreciated value for the existing natural gas ERTs was $2.8 million. Replacement of the electric meters and natural gas ERTs began during the second half of 2018 and is ongoing.

In September 2017, the WUTC approved a Petition to defer the depreciation expense associated with the AMI project, along with a carrying charge, and to seek recovery of the deferral and carrying charge in a future general rate case. Cost savings, such as reduced meter reading costs, will occur during the implementation period, and will offset a portion of the AMI costs not being deferred.

In May 2017, we filed Petitions with the IPUC and the OPUC requesting a depreciable life of 12.5 years for the meter data management system (MDM) related to the AMI project. Both the IPUC and the OPUC approved our request. In addition, in connection with the 2017 Idaho electric general rate case, the settling parties agreed to cost recovery of Idaho's share of the MDM system, effective January 1, 2019. In connection with the approval of the Oregon general rate case settlement, the OPUC approved cost recovery of Oregon's share of the MDM system, effective November 1, 2017.

Avista Utilities

Purchased Gas Adjustments

PGAs are designed to pass through changes in natural gas costs to Avista Utilities' customers with no change in utility margin (operating revenues less resource costs) or net income. In Oregon, we absorb (cost or benefit) 10 percent of the difference between actual and projected natural gas costs included in retail rates for supply that is not hedged. Total net deferred natural gas costs among all jurisdictions were a liability of $2.8 million as of June 30, 2020 and a net liability of $3.2 million as of December 31, 2019.

Power Cost Deferrals and Recovery Mechanisms

The ERM is an accounting method used to track certain differences between Avista Utilities' actual power supply costs, net of wholesale sales and sales of fuel, and the amount included in base retail rates for our Washington customers. Under the ERM, Avista Utilities makes an annual filing on or before April 1 of each year to provide the opportunity for the WUTC staff and other interested parties to review the prudence of and audit the ERM deferred power cost transactions for the prior calendar year. See the 2019 Form 10-K for a full discussion of the mechanics of the ERM and the various sharing bands. Total net deferred power costs under the ERM

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were a liability of $41.8 million as of June 30, 2020, compared to a liability of $37.0 million as of December 31, 2019. These deferred power cost balances represent amounts due to customers. Pursuant to WUTC requirements, should the cumulative deferral balance exceed $30 million in the rebate or surcharge direction, we must make a filing with the WUTC to adjust customer rates to either return the balance to customers or recover the balance from customers.

The cumulative rebate balance exceeds $30 million and as a result, our 2019 filing contained a proposed rate refund. The ERM proceeding was considered with our 2019 general rate case proceeding and a refund was approved and will be returned to customers over a two-year period. See further discussion in the section "Washington General Rate Cases" above.

Avista Utilities has a PCA mechanism in Idaho that allows us to modify electric rates on October 1 of each year with IPUC approval. Under the PCA mechanism, we defer 90 percent of the difference between certain actual net power supply expenses and the amount included in base retail rates for our Idaho customers. The October 1 rate adjustments recover or rebate power supply costs deferred during the preceding July-June twelve-month period. Total net power supply costs deferred under the PCA mechanism were assets of $0.1 million as of June 30, 2020 and $0.3 million as of December 31, 2019. These deferred power cost balances represent amounts due from customers.

Decoupling and Earnings Sharing Mechanisms

Decoupling (also known as an FCA in Idaho) is a mechanism designed to sever the link between a utility's revenues and consumers' energy usage. In each of our jurisdictions, Avista Utilities' electric and natural gas revenues are adjusted so as to be based on the number of customers in certain customer rate classes and assumed "normal" kilowatt hour and therm sales, rather than being based on actual kilowatt hour and therm sales. The difference between revenues based on the number of customers and "normal" sales and revenues based on actual usage is deferred and either surcharged or rebated to customers beginning in the following year. Only residential and certain commercial customer classes are included in our decoupling mechanisms. See the 2019 Form 10-K for a discussion of the mechanisms in each jurisdiction.

Total net cumulative decoupling deferrals among all jurisdictions were regulatory assets of $24.7 million as of June 30, 2020 and $24.3 million as of December 31, 2019. These decoupling assets represent amounts due from customers. Total net earnings sharing balances among all jurisdictions were regulatory liabilities of $0.7 million as of June 30, 2020 and December 31, 2019. These earnings sharing liabilities represent amounts due to customers.

See "Results of Operations - Avista Utilities" for further discussion of the amounts recorded to operating revenues in 2020 and 2019 related to the decoupling and earnings sharing mechanisms.

Results of Operations - Overall

The following provides an overview of changes in our Condensed Consolidated Statements of Income. More detailed explanations are provided, particularly for operating revenues and operating expenses, in the business segment discussions (Avista Utilities, AEL&P, and the other businesses) that follow this section.

The balances included below for utility operations reconcile to the Condensed Consolidated Statements of Income.

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Three months ended June 30, 2020 compared to the three months ended June 30, 2019

The following graph shows the total change in net income attributable to Avista Corp. shareholders for the second quarter of 2019 compared to the second quarter of 2020, as well as the various factors that caused such change (dollars in millions):

 

 

Utility revenues decreased at Avista Utilities when compared to the second quarter of 2019. Electric commercial and industrial loads were lower than the second quarter of 2019 by 13 percent and 8 percent, respectively. The effect of the above decreases in load was partially offset by the effect of an increase in electric and natural gas decoupling rates, higher PGA rates and customer growth. AEL&P's revenues increased from an increase in sales volumes due to weather that was cooler than the prior year.

Non-utility revenues decreased due to the sale of METALfx, which occurred in April 2019.

Utility resource costs decreased at Avista Utilities due to lower fuel for generation and other fuel costs, as well as lower natural gas purchases. The increase at AEL&P was due to an increase in deferred power supply expenses.

The decrease in utility operating expenses was primarily due to decreases in Avista Utilities’ generation and distribution operating and maintenance costs, which was partially offset by an increase in bad debt expense. Additionally, there was a $7.0 million donation commitment made in the second quarter of 2019 that was a one-time donation.

Utility depreciation and amortization increased due to additions to utility plant. Also, in the second quarter of 2020 we were able to utilize approximately $10.9 million ($8.4 million when tax-effected) of electric tax benefits to offset costs associated accelerating the depreciation of Colstrip Units 3 & 4 based on a settlement in Washington. This amount was recorded as a one-time increase to depreciation expense in the second quarter of 2020 and was offset with a decrease to income tax expense. In the second quarter of 2019, a similar item was recorded in Idaho in the amount of $6.4 million ($5.1 million when tax-effected).

The decrease in other was primarily related to a gain on the sale of METALfx during the second quarter of 2019. In addition, there were net losses on investments.

Income taxes decreased primarily due to a decrease in income before taxes. Our effective tax rate was negative 83 percent for the second quarter of 2020 compared to negative 7.5 percent for the second quarter of 2019. The decrease in the tax rate was primarily due to the offset of deferred income taxes against accelerated depreciation for Colstrip as provided in the 2019 Washington general rate case settlement, which was recorded in the second quarter. This amounted to $8.4 million in 2020 as compared to $5.1 million in 2019.

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See "Note 7 of the Notes to Condensed Consolidated Financial Statements" for further details and a reconciliation of our effective tax rate.

Six months ended June 30, 2020 compared to the six months ended June 30, 2019

The following graph shows the total change in net income attributable to Avista Corp. shareholders for the first half of 2020 compared to the first half of 2019, as well as the various factors that caused such change (dollars in millions):

 

 

Utility revenues decreased at Avista Utilities primarily due to a decrease in commercial and industrial electric load as discussed in the COVID-19 section above. The outcome from the 2015 Washington general rate cases decreased revenue by $4.9 million. The above decreases were partially offset by an increase from electric and natural gas decoupling rates, higher PGA rates and customer growth. AEL&P's revenues increased from an increase in sales volumes due to weather that was cooler than the prior year.

Non-utility revenues decreased due to the sale of METALfx, which occurred in April 2019.

Utility resource costs decreased at Avista Utilities due to lower fuel for generation and other fuel costs, as well as lower natural gas purchases. The increase at AEL&P was due to an increase in deferred power supply expenses.

The increase in utility operating expenses was due to an increase at Avista Utilities primarily related to increases in generation and distribution operating and maintenance costs, an accrual for disallowed replacement power during an unplanned outage at Colstrip (see "Regulatory Matters"), and an increase in bad debt expense. Additionally, there was a $7.0 million donation commitment made in the second quarter of 2019 that was a one-time donation.

The merger transaction costs are related to the proposed (now terminated) acquisition by Hydro One. There were no additional costs in 2020 relating to this matter.

Utility depreciation and amortization increased due to additions to utility plant. Also, in the second quarter of 2020 we were able to utilize approximately $10.6 million ($8.4 million when tax-effected) of electric tax benefits to offset costs associated accelerating the depreciation of Colstrip Units 3 & 4 based on a settlement in Washington. This amount was recorded as a one-time increase to

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depreciation expense in the second quarter of 2020 and was offset with a decrease in income tax expense. In the second quarter of 2019, a similar item was recorded in Idaho in the amount of $6.4 million ($5.1 million when tax-effected).

The merger termination fee was related to the termination of the proposed Hydro One acquisition.

Income taxes decreased primarily due to a decrease in income before taxes. Our effective tax rate was 0.9 percent for 2020 compared to 16.7 percent for the second quarter of 2019. The decrease in the tax rate was primarily due to the offset of deferred income taxes against accelerated depreciation for Colstrip as provided in the 2019 Washington general rate case settlement, which was recorded in the second quarter. This amounted to $8.4 million in 2020 as compared to $5.1 million in 2019. See "Note 7 of the Notes to Condensed Consolidated Financial Statements" for further details and a reconciliation of our effective tax rate.

Non-GAAP Financial Measures

The following discussion for Avista Utilities includes two financial measures that are considered “non-GAAP financial measures”: electric utility margin and natural gas utility margin. In the AEL&P section, we include a discussion of utility margin, which is also a non-GAAP financial measure.

Generally, a non-GAAP financial measure is a numerical measure of a company's financial performance, financial position or cash flows that excludes (or includes) amounts that are included (excluded) in the most directly comparable measure calculated and presented in accordance with GAAP. Electric utility margin is electric operating revenues less electric resource costs, while natural gas utility margin is natural gas operating revenues less natural gas resource costs. The most directly comparable GAAP financial measure to electric and natural gas utility margin is utility operating revenues as presented in "Note 16 of the Notes to Condensed Consolidated Financial Statements."

The presentation of electric utility margin and natural gas utility margin is intended to enhance the understanding of operating performance. We use these measures internally and believe they provide useful information to investors in their analysis of how changes in loads (due to weather, economic or other conditions), rates, supply costs and other factors impact our results of operations. Changes in loads, as well as power and natural gas supply costs, are generally deferred and recovered from customers through regulatory accounting mechanisms. Accordingly, the analysis of utility margin generally excludes most of the change in revenue resulting from these regulatory mechanisms. We present electric and natural gas utility margin separately below for Avista Utilities since each business has different cost sources, cost recovery mechanisms and jurisdictions, so we believe that separate analysis is beneficial. These measures are not intended to replace utility operating revenues as determined in accordance with GAAP as an indicator of operating performance. Reconciliations of operating revenues to utility margin are set forth below.

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Results of Operations - Avista Utilities

Three months ended June 30, 2020 compared to the three months ended June 30, 2019

Utility Operating Revenues

The following graphs present Avista Utilities' electric operating revenues and megawatt-hour (MWh) sales for the three months ended June 30, 2020 and 2019 (dollars in millions and MWhs in thousands):

(1)

This balance includes public street and highway lighting, which is considered part of retail electric revenues, and deferrals/amortizations to customers related to federal income tax law changes.

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Total electric operating revenues in the graph above include intracompany sales of $8.8 million and $6.0 million for the three months ended June 30, 2020 and 2019, respectively.

 

 

The following table presents the current year deferrals and the amortization of prior year decoupling balances that are reflected in utility electric operating revenues for the three months ended June 30 (dollars in thousands):

 

 

 

Electric Decoupling Revenues

 

 

 

2020

 

 

2019

 

Current year decoupling deferrals (a)

 

$

5,842

 

 

$

5,159

 

Amortization of prior year decoupling deferrals (b)

 

 

(3,658

)

 

 

533

 

Total electric decoupling revenue

 

$

2,184

 

 

$

5,692

 

 

(a)

Positive amounts are increases in decoupling revenue in the current year and will be surcharged to customers in future years. Negative amounts are decreases in decoupling revenue in the current year and will be rebated to customers in future years.

(b)

Positive amounts are increases in decoupling revenue in the current year and are related to the amortization of rebate balances that resulted in prior years and are being refunded to customers (causing a corresponding decrease in retail revenue from customers) in the current year. Negative amounts are decreases in decoupling revenue in the current year and are related to the amortization of surcharge balances that resulted in prior years and are being surcharged to customers (causing a corresponding increase in retail revenue from customers) in the current year.

Total electric revenues decreased $15.8 million for the second quarter of 2020 as compared to the second quarter of 2019 primarily due to the following:

 

a $3.2 million decrease in retail electric revenue due to a decrease in total MWhs sold (decreased revenues $8.1 million), partially offset by an increase in revenue per MWh (increased revenues $4.9 million).

 

o

The decrease in total retail MWhs sold was primarily the result of a decrease in commercial and industrial sales volumes mostly due to COVID-19 impacts, partially offset by an increase in residential volumes and customer growth. In addition, weather was cooler than normal and cooler than the prior year. Compared to the second quarter

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of 2019, residential electric use per customer increased 5 percent, commercial use per customer decreased 14 percent and industrial use per customer decreased 8 percent. Cooling degree days in Spokane were 21 percent below normal and 42 percent below the prior year. Heating degree days in Spokane were 4 percent below normal, but 23 percent above the second quarter of 2019.

 

o

The increase in revenue per MWh was primarily due to an increase in decoupling rates (as there was a decoupling surcharge in 2020 compared to a decoupling rebate in 2019) and also a general rate increase in Washington, effective April 1, 2020. This was partially offset by a general rate decrease in Idaho, effective December 1, 2019.

 

a $6.2 million decrease in wholesale electric revenues due to a decrease in sales prices (decreased revenues $3.5 million) and a decrease in sales volumes (decreased revenues $2.7 million). The fluctuation in volumes and sales prices we received were primarily the result of our optimization activities.

 

a $3.1 million decrease in sales of fuel as part of thermal generation resource optimization activities.

 

a $3.5 million decrease in electric decoupling revenue primarily due to the amortization of decoupling surcharges from prior years and current year decoupling rebates to residential customers due to higher usage compared to normal, partially related to the Stay-at-Home orders from the Washington and Idaho governments. The above amounts were partially offset by decoupling surcharges to non-residential customers as commercial usage was down compared to normal during the second quarter primarily due to COVID-19 impacts.

The following graphs present Avista Utilities' natural gas operating revenues and therms delivered for the three months ended June 30, 2020 and 2019 (dollars in millions and therms in thousands):

(1)

This balance includes interruptible and industrial revenues, which are considered part of retail natural gas revenues, and deferrals/amortizations to customers related to federal income tax law changes.

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Total natural gas operating revenues in the graph above include intracompany sales of $11.2 million and $6.5 million for the three months ended June 30, 2020 and 2019, respectively.

 

 

The following table presents the current year deferrals and the amortization of prior year decoupling balances that are reflected in utility natural gas operating revenues for the three months ended June 30 (dollars in thousands):

 

 

 

Natural Gas Decoupling Revenues

 

 

 

2020

 

 

2019

 

Current year decoupling deferrals (a)

 

$

2,657

 

 

$

3,138

 

Amortization of prior year decoupling deferrals (b)

 

 

(479

)

 

 

895

 

Total natural gas decoupling revenue

 

$

2,178

 

 

$

4,033

 

 

(a)

Positive amounts are increases in decoupling revenue in the current year and will be surcharged to customers in future years. Negative amounts are decreases in decoupling revenue in the current year and will be rebated to customers in future years.

(b)

Positive amounts are increases in decoupling revenue in the current year and are related to the amortization of rebate balances that resulted in prior years and are being refunded to customers (causing a corresponding decrease in retail revenue from customers) in the current year. Negative amounts are decreases in decoupling revenue in the current year and are related to the amortization of surcharge balances that resulted in prior years and are being surcharged to customers (causing a corresponding increase in retail revenue from customers) in the current year.

Total natural gas revenues increased $1.8 million for the second quarter of 2020 as compared to the second quarter of 2019 primarily due to the following:

 

an $8.1 million increase in natural gas retail revenues due to an increase in retail rates (increased revenues $5.7 million) and an increase in volumes (increased revenues $2.4 million).

 

o

Retail rates increased from higher PGA rates, decoupling rate increases and general rate increases in Oregon, effective January 15, 2020 and Washington, effective April 1, 2020.

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o

Retail natural gas sales volumes increased in the second quarter of 2020 as compared to the second quarter of 2019 primarily due to higher residential usage, resulting from cooler weather in the second quarter and the Stay-at-Home orders associated with COVID-19, partially offset by lower commercial and industrial usage also related to COVID-19. There was also customer growth during the second quarter. Compared to second quarter of 2019, residential use per customer increased 9 percent, commercial use per customer decreased 9 percent and industrial use per customer decreased 9 percent. Heating degree days in Spokane were 4 percent below normal, but 23 percent above the second quarter of 2019. Heating degree days in Medford were 11 percent below normal, but 13 percent above the second quarter of 2019.

 

a $3.0 million decrease in wholesale natural gas revenues due to a decrease in volumes (decreased revenues $2.2 million) and a decrease in prices (decreased revenues $0.8 million). Differences between revenues and costs from sales of resources in excess of retail load requirements and from resource optimization are accounted for through the PGA mechanisms.

 

a $1.9 million decrease in natural gas decoupling revenue primarily related to the amortization of decoupling surcharges from prior years. During the current year commercial usage was down compared to normal during the second quarter due to COVID-19 impacts, which resulted in decoupling surcharges. There were also decoupling surcharges for residential customers. The deferrals in the current year were not as large as those during the second quarter of 2019 as weather varied more than normal in 2019 as compared to 2020.

The following table presents Avista Utilities' average number of electric and natural gas retail customers for the three months ended June 30, 2020 and 2019:

 

 

 

Electric Customers

 

 

Natural Gas Customers

 

 

 

2020

 

 

2019

 

 

2020

 

 

2019

 

Residential

 

 

349,472

 

 

 

344,342

 

 

 

326,504

 

 

 

321,126

 

Commercial

 

 

43,388

 

 

 

42,922

 

 

 

36,149

 

 

 

35,835

 

Interruptible

 

 

 

 

 

 

 

 

38

 

 

 

48

 

Industrial

 

 

1,298

 

 

 

1,307

 

 

 

241

 

 

 

241

 

Public street and highway lighting

 

 

648

 

 

 

606

 

 

 

 

 

 

 

Total retail customers

 

 

394,805

 

 

 

389,177

 

 

 

362,932

 

 

 

357,250

 

 

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Utility Resource Costs

The following graphs present Avista Utilities' resource costs for the three months ended June 30, 2020 and 2019 (dollars in millions):

 

Total electric resource costs in the graph above include intracompany resource costs of $11.2 million and $6.5 million for the three months ended June 30, 2020 and June 30, 2019, respectively.

Total electric resource costs decreased $13.5 million for the second quarter of 2020 as compared to the second quarter of 2019 primarily due to the following:

 

a $3.8 million decrease in power purchased due to a decrease in in wholesale prices (decreased costs $6.6 million), partially offset by an increase in the volume of power purchases (increased costs $2.8 million). The fluctuation in volumes and prices was primarily the result of our optimization activities during the quarter.

 

a $1.0 million decrease in fuel for generation primarily related to a decrease in natural gas prices and a decrease in customer volumes sold (which required less generation to service this load) as compared to the second quarter of 2019.

 

a $0.3 million increase in other fuel costs. This represents fuel and the related derivative instruments that were purchased for generation but were later sold when conditions indicated that it was more economical to sell the fuel as part of the resource optimization process. When the fuel or related derivative instruments are sold, that revenue is included in sales of fuel.

 

an $8.9 million decrease in other electric resource costs, primarily related to increased amortizations associated with the Washington ERM and a residential exchange credit.

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Total natural gas resource costs in the graph above include intracompany resource costs of $8.8 million and $6.0 million for the three months ended June 30, 2020 and June 30, 2019, respectively.

Total natural gas resource costs decreased $0.5 million for the second quarter of 2020 as compared to the second quarter of 2019 primarily due to the following:

 

a $0.7 million increase in natural gas purchased due to an increase in the price of natural gas (increased costs $3.2 million), partially offset by a decrease in volumes (decreased costs $2.5 million).

 

a $1.2 million decrease from net amortizations and deferrals of natural gas costs.

Utility Margin

The following table reconciles Avista Utilities' operating revenues, as presented in "Note 16 of the Notes to Condensed Consolidated Financial Statements" to the Non-GAAP financial measure utility margin for the three months ended June 30, 2020 and 2019 (dollars in thousands):

 

 

 

Electric

 

 

Natural Gas

 

 

Intracompany

 

 

Total

 

 

 

2020

 

 

2019

 

 

2020

 

 

2019

 

 

2020

 

 

2019

 

 

2020

 

 

2019

 

Operating revenues

 

$

213,785

 

 

$

229,591

 

 

$

74,555

 

 

$

72,766

 

 

$

(20,000

)

 

$

(12,549

)

 

$

268,340

 

 

$

289,808

 

Resource costs

 

 

52,092

 

 

 

65,564

 

 

 

34,977

 

 

 

35,491

 

 

 

(20,000

)

 

 

(12,549

)

 

$

67,069

 

 

$

88,506

 

Utility margin

 

$

161,693

 

 

$

164,027

 

 

$

39,578

 

 

$

37,275

 

 

$

 

 

$

 

 

$

201,271

 

 

$

201,302

 

 

Electric utility margin decreased $2.3 million and natural gas utility margin increased $2.3 million.

Electric utility margin decreased primarily due to an increase in net power supply costs as compared to the prior year as costs in the prior year were lower than those recovered through our rates (authorized costs). For the second quarter of 2020, we had a $0.4 million pre-tax benefit under the ERM in Washington, compared to a $6.0 million pre-tax benefit for the second quarter of 2019. For the full year of 2020, we expect to be in a benefit position under the ERM within the 90 percent customer/10 percent Company sharing band. In addition, during the second quarter of 2020, we experienced lower commercial and industrial loads, mainly due to COVID-19, and

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a portion of these loads, primarily industrial loads, are not covered by our decoupling mechanisms. The above decreases were partially offset by customer growth and general rate increases in Washington, effective April 1, 2020.

Natural gas utility margin increased primarily due to a general rate increase in Oregon, effective January 15, 2020 and Washington, effective April 1, 2020, and customer growth.

Intracompany revenues and resource costs represent purchases and sales of natural gas between our natural gas distribution operations and our electric generation operations (as fuel for our generation plants). These transactions are eliminated in the presentation of total results for Avista Utilities and in the condensed consolidated financial statements but are included in the separate results for electric and natural gas presented above.

Six months ended June 30, 2020 compared to the Six months ended June 30, 2019

Utility Operating Revenues

The following graphs present Avista Utilities' electric operating revenues and megawatt-hour (MWh) sales for the six months ended June 30, 2020 and 2019 (dollars in millions and MWhs in thousands):

 

(1)

This balance includes public street and highway lighting, which is considered part of retail electric revenues, and deferrals/amortizations to customers related to federal income tax law changes.

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Total electric operating revenues in the graph above include intracompany sales of $14.9 million and $25.7 million for the six months ended June 30, 2020 and 2019, respectively.

 

The following table presents the current year deferrals and the amortization of prior year decoupling balances that are reflected in utility electric operating revenues for the six months ended June 30 (dollars in thousands):

 

 

 

Electric Decoupling

Revenues

 

 

 

2020

 

 

2019

 

Current year decoupling deferrals (a)

 

$

10,973

 

 

$

2,478

 

Amortization of prior year decoupling deferrals (b)

 

 

(8,266

)

 

 

1,609

 

Total electric decoupling revenue

 

$

2,707

 

 

$

4,087

 

 

(a)

Positive amounts are increases in decoupling revenue in the current year and will be surcharged to customers in future years. Negative amounts are decreases in decoupling revenue in the current year and will be rebated to customers in future years.

(b)

Positive amounts are increases in decoupling revenue in the current year and are related to the amortization of rebate balances that resulted in prior years and are being refunded to customers (causing a corresponding decrease in retail revenue from customers) in the current year. Negative amounts are decreases in decoupling revenue in the current year and are related to the amortization of surcharge balances that resulted in prior years and are being surcharged to customers (causing a corresponding increase in retail revenue from customers) in the current year.

Total electric revenues decreased $26.1 million for the first half of 2020 as compared to the first half of 2019 primarily due to the following:

 

an $11.7 million decrease in retail electric revenue due to a decrease in total MWhs sold (decreased revenues $18.7 million), partially offset by an increase in revenue per MWh (increased revenues $7.0 million).

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o

The decrease in total retail MWhs sold was primarily the result of a decrease in sales volumes in all customer classes due to a combination of impacts associated with COVID-19, as well as weather that was milder than normal and the prior year. These were partially offset by residential and commercial customer growth. Compared to the first half of 2019, residential electric use per customer decreased 4 percent, commercial use per customer decreased 8 percent and industrial use per customer decreased 6 percent. Heating degree days in Spokane were 6 percent below normal and 9 percent below the first half of 2019. Cooling degree days were 21 percent below normal and 42 percent below the first half of 2019.

 

o

The increase in revenue per MWh was primarily due to an increase in decoupling rates (as there was a decoupling surcharge in 2020 compared to a decoupling rebate in 2019) and a general rate increase in Washington, effective April 1, 2020. This was partially offset by a general rate decrease in Idaho, effective December 1, 2019.

 

a $10.8 million decrease in sales of fuel as part of thermal generation resource optimization activities.

 

a $1.4 million decrease in electric decoupling revenue primarily related to the amortization of decoupling surcharges from prior years. This was partially offset by decoupling surcharges for non-residential customers as commercial usage was down compared to normal during the second quarter due to COVID-19 impacts. In addition, weather was milder than normal, which also resulted in decoupling surcharges.

 

the $2.5 million decrease in other electric revenues was primarily related to a $1.4 million accrual for customer refunds related to our 2015 Washington general rate case that was remanded back to the WUTC during 2019. See "Regulatory Matters" for further discussion.

The following graphs present Avista Utilities' natural gas operating revenues and therms delivered for the six months ended June 30, 2020 and 2019 (dollars in millions and therms in thousands):

 

(1)

This balance includes interruptible and industrial revenues, which are considered part of retail natural gas revenues, and deferrals/amortizations to customers related to federal income tax law changes.

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Total natural gas operating revenues in the graph above include intracompany sales of $24.1 million and $30.3 million for the six months ended June 30, 2020 and 2019, respectively.

 

The following table presents the current year deferrals and the amortization of prior year decoupling balances that are reflected in utility natural gas operating revenues for the six months ended June 30 (dollars in thousands):

 

 

 

Natural Gas Decoupling

Revenues

 

 

 

2020

 

 

2019

 

Current year decoupling deferrals (a)

 

$

(899

)

 

$

(2,968

)

Amortization of prior year decoupling deferrals (b)

 

 

(1,859

)

 

 

3,948

 

Total natural gas decoupling revenue

 

$

(2,758

)

 

$

980

 

 

(a)

Positive amounts are increases in decoupling revenue in the current year and will be surcharged to customers in future years. Negative amounts are decreases in decoupling revenue in the current year and will be rebated to customers in future years.

(b)

Positive amounts are increases in decoupling revenue in the current year and are related to the amortization of rebate balances that resulted in prior years and are being refunded to customers (causing a corresponding decrease in retail revenue from customers) in the current year. Negative amounts are decreases in decoupling revenue in the current year and are related to the amortization of surcharge balances that resulted in prior years and are being surcharged to customers (causing a corresponding increase in retail revenue from customers) in the current year.

Total natural gas revenues decreased $12.9 million for the first half of 2020 as compared to the first half of 2019 primarily due to the following:

 

an $18.3 million increase in natural gas retail revenues due to an increase in retail rates (increased revenues $28.4 million), partially offset by a decrease in volumes (decreased revenues $10.1 million).

 

o

Retail rates increased from higher PGA rates, decoupling rate increases and general rate increases in Oregon, effective January 15, 2020 and Washington, effective April 1, 2020.

 

o

Retail natural gas sales decreased in the first half of 2020 as compared to the first half of 2019 primarily due to lower residential and commercial usage, partially offset by customer growth. Compared to the first half of 2019,

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residential use per customer decreased 7 percent and commercial use per customer decreased 10 percent. Heating degree days in Spokane were 6 percent below normal, and 9 percent below the first half of 2019. Heating degree days in Medford were normal, and comparable to the first half of 2019.

 

a $23.0 million decrease in wholesale natural gas revenues due to a decrease in prices (decreased revenues $22.8 million) and a decrease in volumes (decreased revenues $0.2 million). Differences between revenues and costs from sales of resources in excess of retail load requirements and from resource optimization are accounted for through the PGA mechanisms.

 

a $3.8 million decrease in natural gas decoupling revenue primarily related to the amortization of decoupling surcharges from prior years. Also, during the first quarter, there were decoupling rebates to customers and this was partially offset by customer surcharges during the second quarter, mainly due to weather that was milder than normal and due to the impacts of COVID-19.

 

the $3.4 million decrease in other natural gas revenues was primarily related to a $3.6 million accrual for customer refunds related to our 2015 Washington general rate case that was remanded back to the WUTC during 2019. See "Regulatory Matters" for further discussion.

The following table presents Avista Utilities' average number of electric and natural gas retail customers for the six months ended June 30, 2020 and 2019:

 

 

 

Electric

Customers

 

 

Natural Gas

Customers

 

 

 

2020

 

 

2019

 

 

2020

 

 

2019

 

Residential

 

 

349,420

 

 

 

344,140

 

 

 

326,315

 

 

 

320,309

 

Commercial

 

 

43,344

 

 

 

42,898

 

 

 

36,172

 

 

 

35,771

 

Interruptible

 

 

 

 

 

 

 

 

41

 

 

 

45

 

Industrial

 

 

1,296

 

 

 

1,310

 

 

 

241

 

 

 

240

 

Public street and highway lighting

 

 

643

 

 

 

604

 

 

 

 

 

 

 

Total retail customers

 

 

394,703

 

 

 

388,952

 

 

 

362,768

 

 

 

356,365

 

 

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Utility Resource Costs

The following graphs present Avista Utilities' resource costs for the six months ended June 30, 2020 and 2019 (dollars in millions):

 

Total electric resource costs in the graph above include intracompany resource costs of $24.1 million and $30.3 million for the six months ended June 30, 2020 and June 30, 2019, respectively.

Total electric resource costs decreased $31.8 million for the first half of 2020 as compared to the first half of 2019 primarily due to the following:

 

an $8.0 million decrease in power purchased due to a decrease in wholesale prices (decreased costs $5.6 million) and a decrease in the volume of power purchases (decreased costs $2.4 million). The fluctuation in volumes and prices was primarily the result of our optimization activities during the quarter.

 

a $9.8 million decrease in fuel for generation primarily related to a decrease in natural gas prices and a decrease in customer volumes sold (which resulted in less generation required to serve our load).

 

a $6.0 million decrease in other fuel costs. This represents fuel and the related derivative instruments that were purchased for generation but were later sold when conditions indicated that it was more economical to sell the fuel as part of the resource optimization process. When the fuel or related derivative instruments are sold, that revenue is included in sales of fuel.

 

an $8.0 million decrease in other electric resource costs, primarily related to increased amortizations associated with the Washington ERM, a residential exchange credit and demand side management programs.

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Total natural gas resource costs in the graph above include intracompany resource costs of $14.9 million and $25.7 million for the three months ended June 30, 2020 and June 30, 2019, respectively.

Total natural gas resource costs decreased $15.8 million for the first half of 2020 as compared to the first half of 2019 primarily due to the following:

 

a $58.7 million decrease in natural gas purchased due to a decrease in the price of natural gas (decreased costs $56.1 million) and a decrease in volumes purchased (decreased costs $2.6 million).

 

a $42.9 million increase from net amortizations and deferrals of natural gas costs, primarily due to a spike in natural gas prices during the first quarter of 2019 from a natural gas supply disruption in Canada, which resulted in a significant amount of PGA deferrals during that period.

Utility Margin

The following table reconciles Avista Utilities' operating revenues, as presented in "Note 16 of the Notes to Condensed Consolidated Financial Statements" to the Non-GAAP financial measure utility margin for the six months ended June 30 (dollars in thousands):

 

 

 

Electric

 

 

Natural Gas

 

 

Intracompany

 

 

Total

 

 

 

2020

 

 

2019

 

 

2020

 

 

2019

 

 

2020

 

 

2019

 

 

2020

 

 

2019

 

Operating revenues

 

$

459,993

 

 

$

486,058

 

 

$

224,505

 

 

$

237,443

 

 

$

(38,953

)

 

$

(55,991

)

 

$

645,545

 

 

$

667,510

 

Resource costs

 

 

127,623

 

 

 

159,445

 

 

 

107,955

 

 

 

123,764

 

 

 

(38,953

)

 

 

(55,991

)

 

 

196,625

 

 

 

227,218

 

Utility margin

 

$

332,370

 

 

$

326,613

 

 

$

116,550

 

 

$

113,679

 

 

$

 

 

$

 

 

$

448,920

 

 

$

440,292

 

 

Electric utility margin increased $5.8 million and natural gas utility margin increased $2.9 million.

Electric utility margin increased primarily due to a decrease in net power supply costs due to power purchase prices and thermal fuel costs that were lower than those recovered through our rates (authorized costs). For the first half of 2020, we had a $5.6 million pre-tax benefit under the ERM in Washington, compared to a $3.5 million pre-tax benefit for the first half of 2019. For the full year of 2020, we expect to be in a benefit position under the ERM within the 90 percent customer/10 percent Company sharing band. In addition, electric utility margin was positively impacted by a general rate increase in Washington, effective April 1, 2020 and customer

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growth. The above increases were partially offset by lower commercial and industrial loads in the second quarter of 2020, mainly due to COVID-19 and a portion of these loads, especially the industrial loads are not covered by our decoupling mechanisms. Also, in the first quarter of 2020 we had an accrual for customer refunds of $1.4 million related to our 2015 Washington general rate case that was remanded back to the WUTC during 2019. See "Regulatory Matters" for further discussion

Natural gas utility margin increased primarily due to general rate increases in Oregon, effective January 15, 2020 and Washington, effective April 1, 2020 and customer growth. These increases were partially offset by an accrual for customer refunds of $3.6 million related to our 2015 Washington general rate case that was remanded back to the WUTC during 2019. See "Regulatory Matters" for further discussion.

Intracompany revenues and resource costs represent purchases and sales of natural gas between our natural gas distribution operations and our electric generation operations (as fuel for our generation plants). These transactions are eliminated in the presentation of total results for Avista Utilities and in the condensed consolidated financial statements but are included in the separate results for electric and natural gas presented above.

Results of Operations - Alaska Electric Light and Power Company

Three months ended June 30, 2020 compared to the three months ended June 30, 2019 and six months ended June 30, 2020 compared to the six months ended June 30, 2019

Net income for AEL&P was $1.3 million for the three months ended June 30, 2020 compared to $1.1 million for the three months ended June 30, 2019. Net income was $4.7 million for the six months ended June 30, 2020 compared to $4.6 million for the six months ended June 30, 2019.

The following table presents AEL&P's operating revenues, resource costs and resulting utility margin for the three and six months ended June 30 (dollars in thousands):

 

 

 

Three months ended June 30,

 

 

Six months ended June 30,

 

 

 

2020

 

 

2019

 

 

2020

 

 

2019

 

Operating revenues

 

$

9,997

 

 

$

8,743

 

 

$

22,199

 

 

$

19,624

 

Resource costs (benefit)

 

 

896

 

 

 

(67

)

 

887

 

 

 

(1,432

)

Utility margin

 

$

9,101

 

 

$

8,810

 

 

$

21,312

 

 

$

21,056

 

 

Electric revenues increased for the second quarter of 2020 primarily due to higher sales volumes to residential and commercial customers for 2020 as compared to 2019. This resulted from weather that was cooler than the prior year, as well as more hydroelectric generation than the second quarter of 2019.

AEL&P had low hydroelectric generation during the first half of 2019, which limited energy provided to their interruptible customers. A portion of the sales to interruptible customers is used to reduce the overall cost of power to AEL&P's firm customers. When interruptible sales are below a certain threshold, AEL&P recognizes a regulatory asset and records a reduction to deferred power supply costs (resource costs) to reflect a future billable amount to its firm customers when the cost of power rates are reset. During the first half of 2020, hydroelectric generation returned to normal levels, which resulted in less resource costs compared to the first half of 2019. While the COVID-19 pandemic and a challenged Alaska economy may introduce unpredictability into the remainder of 2020, AEL&P has the capacity to manage costs to adapt.

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Results of Operations - Other Businesses

Net loss for our other businesses was $1.5 million for the three months ended June 30, 2020 compared to net income of $3.0 million for the three months ended June 30, 2019. Net loss was $2.4 million for the six months ended June 30, 2020 compared to net income of $3.4 million for the six months ended June 30, 2019.

During the second quarter of 2020, we had net investment losses on some of our investments. This is compared to the second quarter of 2019 that resulted in net investment gains, primarily related to the sale of METALfx. See “Note 18 of the Notes to Condensed Consolidated Financial Statements” for further discussion on the sale of METALfx.

Critical Accounting Policies and Estimates

The preparation of our consolidated financial statements in conformity with GAAP requires us to make estimates and assumptions that affect amounts reported in the consolidated financial statements. Changes in these estimates and assumptions are considered reasonably possible and may have a material effect on our consolidated financial statements and thus actual results could differ from the amounts reported and disclosed herein. Our critical accounting policies that require the use of estimates and assumptions were discussed in detail in the 2019 Form 10-K and have not changed materially.

Liquidity and Capital Resources

Overall Liquidity

We expect that COVID-19 will have a negative impact on our overall liquidity. For 2020, we expect our net cash flows from operations to decrease primarily due to lower expected revenues from retail sales of electricity and natural gas and lower payments from customers.

In response to potential liquidity needs, in April 2020, we entered into a $100 million credit agreement, see "Note 9 of the Notes to Condensed Consolidated Financial Statements."

Other than COVID-19 impacts, our sources of overall liquidity and the requirements for liquidity have not materially changed in the six months ended June 30, 2020. See the 2019 Form 10-K for further discussion.

As of June 30, 2020, we had $159.6 million of available liquidity under the Avista Corp. committed line of credit and $25.0 million under the AEL&P committed line of credit. After considering the impacts of COVID-19, with our $400.0 million credit facility that expires in April 2022, AEL&P's $25.0 million credit facility that expires in November 2024 and the $100.0 million credit agreement that expires in April 2021, we believe that we have adequate liquidity to meet our needs for the next 12 months.

Review of Cash Flow Statement

Operating Activities

Net cash provided by operating activities was $199.9 million for the six months ended June 30, 2020 compared to $252.7 million for the six months ended June 30, 2019. The decrease in net cash provided by operating activities primarily relates to a termination fee of $103.0 million received in 2019 upon the termination of the Hydro One transaction. The termination fee was used for reimbursing our transaction costs incurred from 2017 to 2019 which totaled approximately $51.0 million, including income taxes. The balance of the termination fee was used for general corporate purposes and reduced our need for external financing. Our total transaction costs were $19.7 million (pre-tax) for 2019 and we also incurred approximately $15.7 million in taxes in 2019.

The above decrease in net cash provided by operating activities was partially offset by power and natural gas deferrals which decreased during 2020 due to lower natural gas prices during the year (which increased cash flows by $1.8 million) as compared to a decrease to operating cash flows of $47.7 million in 2019. As compared to 2019, net current assets and liabilities decreased by $41.8 million.

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Investing Activities

Net cash used in investing activities was $191.8 million for the six months ended June 30, 2020, compared to $190.0 million for the six months ended June 30, 2019. During the six months ended June 30, 2020, we paid $189.5 million for utility capital expenditures compared to $200.0 million for the six months ended June 30, 2019. Also, during 2020, we received proceeds from the sale of an equity investment (net of cash sold and amounts held in escrow) of $5.1 million.

Financing Activities

Net cash provided by financing activities was $98.4 million for the six months ended June 30, 2020, compared to cash used of $60.1 million for the six months ended June 30, 2019. Due to the termination fee described above, we were able to reduce our short-term borrowings during the first quarter of 2019, as evidenced by the $21.0 million decrease in short-term borrowings during 2019. For 2020, we had an increase of $135.2 million in short term borrowings, primarily related to the credit agreement entered into in April 2020. See “Note 9 of Notes to Condensed Consolidated Financial Statements” for further discussion.

Capital Resources

Our consolidated capital structure, including the current portion of long-term debt and short-term borrowings, and excluding noncontrolling interests, consisted of the following as of June 30, 2020 and December 31, 2019 (dollars in thousands):

 

 

 

June 30, 2020

 

 

December 31, 2019

 

 

 

Amount

 

 

Percent

of total

 

 

Amount

 

 

Percent

of total

 

Current portion of long-term debt and leases

 

$

59,087

 

 

 

1.4

%

 

$

58,928

 

 

 

1.4

%

Short-term borrowings

 

 

321,000

 

 

 

7.3

%

 

 

185,800

 

 

 

4.4

%

Long-term debt to affiliated trusts

 

 

51,547

 

 

 

1.2

%

 

 

51,547

 

 

 

1.2

%

Long-term debt and leases

 

 

1,964,773

 

 

 

44.9

%

 

 

1,961,083

 

 

 

46.7

%

Total debt

 

 

2,396,407

 

 

 

54.8

%

 

 

2,257,358

 

 

 

53.8

%

Total Avista Corporation shareholders’ equity

 

 

1,975,038

 

 

 

45.2

%

 

 

1,939,284

 

 

 

46.2

%

Total

 

$

4,371,445

 

 

 

100.0

%

 

$

4,196,642

 

 

 

100.0

%

 

Our shareholders’ equity increased $35.8 million during the first six months of 2020 primarily due to net income and the issuance of common stock, partially offset by dividends.

We need to finance capital expenditures and acquire additional funds for operations from time to time. The cash requirements needed to service our indebtedness, both short-term and long-term, reduce the amount of cash flow available to fund capital expenditures, purchased power, fuel and natural gas costs, dividends and other requirements.

Committed Lines of Credit

Avista Corp. has a committed line of credit with various financial institutions in the total amount of $400.0 million. During the second quarter, we amended and extended, for one additional year, the revolving line of credit agreement for a revised expiration date of April 2022, with the option to extend for an additional one year period. The committed line of credit is secured by non-transferable first mortgage bonds we issued to the agent bank that would only become due and payable in the event, and then only to the extent, that we default on our obligations under the committed line of credit.

The Avista Corp. credit facility contains customary covenants and default provisions, including a covenant which does not permit our ratio of “consolidated total debt” to “consolidated total capitalization” to be greater than 65 percent at any time. As of June 30, 2020, we were in compliance with this covenant with a ratio of 54.8 percent.

AEL&P has a $25.0 million committed line of credit that expires in November 2024. As of June 30, 2020, there were no borrowings or letters of credit outstanding under this committed line of credit.

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The AEL&P credit facility contains customary covenants and default provisions including a covenant which does not permit the ratio of “consolidated total debt at AEL&P” to “consolidated total capitalization at AEL&P” (including the impact of the Snettisham obligation) to be greater than 67.5 percent at any time. As of June 30, 2020, AEL&P was in compliance with this covenant with a ratio of 52.6 percent.

Balances outstanding and interest rates of borrowings under Avista Corp.'s committed line of credit were as follows as of and for the six months ended June 30 (dollars in thousands):

 

 

 

2020

 

 

2019

 

Borrowings outstanding at end of period

 

$

221,000

 

 

$

169,000

 

Letters of credit outstanding at end of period

 

$

19,373

 

 

$

18,603

 

Maximum borrowings outstanding during the period

 

$

221,000

 

 

$

190,000

 

Average borrowings outstanding during the period

 

$

181,373

 

 

$

114,331

 

Average interest rate on borrowings during the period

 

 

1.77

%

 

 

3.31

%

Average interest rate on borrowings at end of period

 

 

1.22

%

 

 

3.26

%

 

As of June 30, 2020, Avista Corp. and its subsidiaries were in compliance with all of the covenants of their financing agreements, and none of Avista Corp.'s subsidiaries constituted a “significant subsidiary” as defined in Avista Corp.'s committed line of credit.

In April 2020, we entered into a $100.0 million credit agreement with an expiration date of April 2021. We borrowed the entire $100.0 million available under this agreement. See "Note 9 of the Notes to Condensed Consolidated Financial Statements."

The credit agreement contains customary covenants and default provisions, including a covenant not to permit the ratio of “consolidated total debt” to “consolidated total capitalization” of Avista Corp. to be greater than 65 percent at any time.

Liquidity Expectations

During 2020, we expect to issue approximately $165.0 million of long-term debt and up to $70.0 million of equity (including $23.9 million issued during the six months ended June 30, 2020) in order to refinance maturing long-term debt, and fund planned capital expenditures.

After considering the impacts of COVID-19, including the expectation of lower net operating cash flows, and the expected issuances of long-term debt and equity during 2020, we expect net cash flows from operations, together with cash available under our committed lines of credit and the $100.0 million borrowed under the credit agreement entered in April, to provide adequate resources to fund capital expenditures, dividends, and other contractual commitments.

Capital Expenditures

We are making capital investments to enhance service and system reliability for our customers and replace aging infrastructure. Our estimated capital expenditures for 2020 through 2022 have not materially changed during the six months ended June 30, 2020. It is possible that prolonged economic restrictions or business interruptions could cause a decrease in our utility capital expenditures. See the 2019 Form 10-K for further information on our expected capital expenditures.

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Off-Balance Sheet Arrangements

As of June 30, 2020, we had $19.4 million in letters of credit outstanding under our $400.0 million committed line of credit, compared to $21.5 million as of December 31, 2019.

Pension Plan

Avista Utilities

In the six months ended June 30, 2020 we contributed $14.6 million to the pension plan and we expect to contribute $22.0 million in 2020. We expect to contribute a total of $150.0 million to the pension plan in the period 2020 through 2024, with annual contributions of $42.0 million in 2021 and 2022 and $22.0 million in 2023 and 2024.

The final determination of pension plan contributions for future periods is subject to multiple variables, most of which are beyond our control, including changes to the fair value of pension plan assets, changes in actuarial assumptions (in particular the discount rate used in determining the benefit obligation), or changes in federal legislation. We may change our pension plan contributions in the future depending on changes to any variables, including those listed above.

Disruptions and overall declines in the financial markets have decreased the fair value of pension plan assets and lower discount rates will increase the pension liability. This could ultimately increase future pension plan funding requirements and expenses. The impact on pension plan assets is mitigated as a significant portion of the assets are fixed-income securities with a target of 35 percent invested in equity securities. The impact on pension expense is also mitigated by pension accounting under GAAP, given that expense is based on the long-term rate of return which should be less affected by short-term market fluctuations.

See "Note 6 of the Notes to Condensed Consolidated Financial Statements" for additional information regarding the pension plan.

Contractual Obligations

Our future contractual obligations have not materially changed during the six months ended June 30, 2020, except for in April 2020, we entered into a $100.0 million credit agreement with a maturity date of April 2021 and the extension of the $400.0 million committed line of credit with an expiration date of April 2022. See "Note 9 of the Notes to Condensed Consolidated Financial Statements."

See the 2019 Form 10-K for our contractual obligations.

Environmental Issues and Contingencies

Our environmental issues and contingencies disclosures have not materially changed during the six months ended June 30, 2020 except as discussed below:

Coal Ash Management/Disposal

In 2015, the EPA issued a final rule regarding coal combustion residuals (CCRs), also termed coal combustion byproducts or coal ash. The CCR rule has been the subject of ongoing litigation. In August 2018, the D.C. Circuit struck down provisions of the rule. Colstrip, of which we are a 15 percent owner of Units 3 & 4, produces this byproduct. On December 2, 2019, a proposed revision to the rule was published in the Federal Register to address the D.C. Circuit's decision. The rule includes technical requirements for CCR landfills and surface impoundments under Subtitle D of the Resource Conservation and Recovery Act, the nation's primary law for regulating solid waste. The Colstrip owners developed a multi-year compliance plan to address the CCR requirements with existing state obligations expressed largely by the 2012 Administrative Order on Consent (AOC) with Montana Department of Environmental Quality (MDEQ). These requirements continue despite the 2018 federal court ruling.

The AOC requires MDEQ provide an ongoing public process which recently approved the Remedy and Closure plans for the three major areas of Colstrip. The AOC also requires the Colstrip owners to provide financial assurance primarily in the form of surety bonds, to secure each owner’s pro rata share of various anticipated closure and remediation obligations. Avista Corp. is responsible for

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its share of two major areas; the Plant Site Area and the Effluent Holding Pond (EHP) Area. Generally, the plans include the removal of Boron, Chloride, and Sulfate from the groundwater, closure of the existing ash storage ponds, and installation of a new water treatment system to convert the facility to a dry ash storage. Avista Corp. has posted three surety bonds totaling approximately $23 million. This amount will be updated annually, decreasing over time as remediation activities are completed.

Oregon Legislation and Regulatory Actions

GHG Reduction Targets

The State of Oregon has adopted non-binding targets to reduce GHG (Greenhouse Gas) emissions. The State enacted its targets with an expectation of reaching the targets through a combination of renewable energy standards, eventual carbon pricing mechanisms, such as cap and trade regulation or a carbon tax, and assorted “complementary policies.”  However, no specific reductions are mandated as yet. The State’s targets have been evaluated by state institutions against the aims of the Paris Climate Accord of 2016, which include limiting the increase in global average temperatures to at least below 2 degrees Celsius above pre-industrial levels and pursuing efforts to restrict the temperature increase to 1.5 degrees Celsius above pre-industrial levels. On March 10, 2020, Oregon Governor Kate Brown issued Executive Order No. 20-04, “Directing State Agencies to Take Actions to Reduce and Regulate Greenhouse Gas Emissions.” The Executive Order launches rulemaking proceedings for every Oregon agency with jurisdiction over greenhouse gas-related matters, with the aim of reducing Oregon’s overall GHG emissions to 80% below 1990 levels by 2050. Oregon agencies, including the Department of Environmental Quality (DEQ) and the Public Utility Commission, issued reports discussing general intent to carry out the Executive Order. DEQ is tasked with developing rules for a cap and reduce program that would apply to Avista’s gas distribution business in Oregon. The agency intends to conduct informal and broad stakeholder consultation during the remainder of 2020. We cannot reasonably predict what regulatory proceedings will arise from the Executive Order, nor how the state legislature may undertake additional requirements or revise the State's targets in the future. We intend to seek recovery of any new costs associated with these reduction targets, or any new reduction targets, through the regulatory process.

Cabinet Gorge Total Dissolved Gas Abatement Plan

Dissolved atmospheric gas levels (referred to as "Total Dissolved Gas" or "TDG") in the Clark Fork River exceed state of Idaho and federal water quality numeric standards downstream of Cabinet Gorge particularly during periods when excess river flows must be diverted over the spillway. Under the terms of the Clark Fork Settlement Agreement as incorporated in Avista Corp.’s FERC license for the Clark Fork Project, Avista Corp. works in consultation with agencies, tribes and other stakeholders to address this issue through structural modifications to the spillgates, monitoring and analysis. After extensive testing, Clark Fork Settlement Agreement stakeholders have agreed that no further spillway modifications are justified. For the remainder of the FERC License term, Avista Corp. will continue to mitigate remaining impacts of TDG while considering the potential for new approaches to further reduce TDG.  The Company continues to work with stakeholders to determine the degree to which TDG abatement reduces future mitigation obligations. The Company has sought, and intends to continue to seek recovery, through the ratemaking process, of all operating and capitalized costs related to this issue.

Hazardous Air Pollutants (HAPs)

In April 2016, the Mercury Air Toxic Standards (MATS), an EPA rule for coal-and oil-fired sources, became effective for all Colstrip units.  Colstrip has already implemented applicable MATS control measures to comply with the MATS rule, and continues to monitor potential changes in the rule to determine additional compliance obligations, if any.  Colstrip performs compliance assurance stack testing on a quarterly basis to meet the MATS site-wide limitation for Particulate Matter (PM) emissions (0.03 lbs./MMBtu). In June 2018, the Montana Department of Environmental Quality (MDEQ) was notified of a PM emission deviation by Talen Montana, LLC (Talen), the plant operator, for the testing performed on June 21, 2018. As a result, Unit 3 was promptly removed from service. For similar reasons, Unit 4 was removed from service on June 29, 2018.

Talen proposed, and the MDEQ acknowledged, that limited operation of Units 3 & 4 for the evaluation of a corrective action and/or data gathering related to potential corrective action was a prudent approach to solving the issue. An extensive inspection was conducted including: the coal supply, coal mills, boiler, combustion, ductwork, air preheater, scrubbers, and the stack. Talen

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implemented cleaning, adjustments, troubleshooting, testing, and other corrective actions. As a part of the corrective action, new flow balancing plates were installed in all Unit 3 & 4 scrubber vessels to further enhance PM removal efficiency. PM testing in September 2018 on Units 3 & 4 demonstrated compliance with the MATS. Both of these compliance tests were witnessed by the MDEQ. With the passing of the PM testing with MATS compliance, Talen, the Colstrip Operator returned both Units 3 & 4 to service in September 2018.

Due to the June 2018 failure to meet the MATS standard, Colstrip Units 3 & 4 were subject to potential MDEQ enforcement action. In lieu of such an action, in December 2019, Talen and MDEQ entered a Stipulated Consent Decree providing for a cash penalty, partially offset by an agreement by Talen to fund specified Supplemental Environmental Projects, as well as additional monitoring activities. The total amount of the cash penalty allocable to the Company is not material.  However, PacifiCorp, PSE, and the Company engaged in a consolidated proceeding before the WUTC to determine the recoverability of replacement power costs incurred during the period that Units 3 & 4 were out of service. On March 25, 2020, the Company received an order from the WUTC, which, among other outcomes, rebated approximately $3 million that was disallowed by the Commission for the cost of replacement power during the unplanned outage at Colstrip in 2018.

Colstrip Coal Contract

Colstrip, which is operated by Talen, is supplied with fuel from adjacent coal reserves under coal supply and transportation agreements. The contract for coal supply extended through 2019. Several of the co-owners of Colstrip, including the Company, have since negotiated an extension to the coal contract that runs through December 31, 2025. In January 2020, the Staff of the WUTC submitted a Petition to Initiate Joint Investigation to the WUTC to investigate the contract. In their petition, the WUTC Staff is proposing one proceeding involving the three joint owners of Colstrip Units 3 & 4 and the focus of their proposed investigation is to review the overall prudency of the new contract and any production tax credits associated with the contract. On March 13, 2020, the WUTC denied the WUTC Staff’s position.

Wildfire Resiliency Plan

We are implementing additional measures to enhance our ability to mitigate the potential for, and impact of, wildfires within our service territories. Building on prevention and response strategies that have been in place many years, we created a new comprehensive 10-year Wildfire Resiliency Plan that includes improved defense strategies and operating practices for a more resilient system.

We have spent the last year developing the Wildfire Resiliency Plan through a series of internal workshops, industry research and engagement with state and local fire agencies. Improvements to infrastructure and operational practices were identified as key components to the plan. These key components are categorized into the following categories: grid hardening, vegetation management, situational awareness, operations and emergency response, and worker and public safety.

We expect to spend approximately $330 million implementing the plan components over the life of the 10-year plan.

Request for Proposals for Renewable Energy

We are seeking proposals from renewable energy project developers who are capable of constructing, owning, and operating up to 120 average MW’s (aMW’s) whether through one or multiple proposals with a minimum net annual output of 20 aMW. We are not considering a self-build option for this facility or facilities.

Our intent is to secure the output from renewable generation resources, including electricity, capacity and associated environmental attributes. Our interest in acquiring new renewable energy resources is to offset market purchases and fossil-fuel thermal generation. This is consistent with our 2020 Integrated Resource Plan which identifies that the utility will consider acquiring additional resources if such resources have lower long-term cost than electric market alternatives.

See the 2019 Form 10-K for further discussion of environmental issues and contingencies.

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Enterprise Risk Management

The material risks to our businesses, and our mitigation process and procedures to address these risks, were discussed in our 2019 Form 10-K and have not materially changed during the six months ended June 30, 2020, other than the changes noted due to COVID-19. See the 2019 Form 10-K.

Financial Risk

Our financial risks have not materially changed during the six months ended June 30, 2020, other than the changes noted due to COVID-19. Refer to the 2019 Form 10-K. The financial risks included below are required interim disclosures, even if they have not materially changed from December 31, 2019.

Interest Rate Risk

We use a variety of techniques to manage our interest rate risks. We have an interest rate risk policy and have established a policy to limit our variable rate exposures to a percentage of total capitalization. Additionally, interest rate risk is managed by monitoring market conditions when timing the issuance of long-term debt and optional debt redemptions and establishing fixed rate long-term debt with varying maturities. See "Note 5 of the Notes to Condensed Consolidated Financial Statements" for a summary of our interest rate swap derivatives outstanding as of June 30, 2020 and December 31, 2019 and the amount of additional collateral we would have to post in certain circumstances. In addition, see "Regulatory Matters" for a discussion of commitments we made in Oregon surrounding the independent review of our interest rate hedging practices.

Credit Risk

Avista Utilities' contracts for the purchase and sale of energy commodities can require collateral in the form of cash or letters of credit. As of June 30, 2020, we had no cash deposited as collateral and letters of credit of $15.3 million outstanding related to our energy derivative contracts. Price movements and/or a downgrade in our credit ratings could impact further the amount of collateral required. See “Credit Ratings” in the 2019 Form 10-K for further information. For example, in addition to limiting our ability to conduct transactions, if our credit ratings were lowered to below “investment grade” based on our positions outstanding at June 30, 2020 (including contracts that are considered derivatives and those that are considered non-derivatives), we would potentially be required to post the following additional collateral (in thousands):

 

 

 

June 30, 2020

 

Additional collateral taking into account contractual thresholds

 

$

14,051

 

Additional collateral without contractual thresholds

 

 

13,562

 

 

Under the terms of interest rate swap derivatives that we enter into periodically, we may be required to post cash or letters of credit as collateral depending on fluctuations in the fair value of the instrument. As of June 30, 2020, we had interest rate swap derivatives outstanding with a notional amount totaling $175.0 million and we had cash deposited as collateral in the amount of $11.0 million and no letters of credit outstanding for these interest rate swap derivatives. If our credit ratings were lowered to below “investment grade” based on our interest rate swap derivatives outstanding at June 30, 2020, we would potentially be required to post the following additional collateral (in thousands):

 

 

 

June 30, 2020

 

Additional collateral taking into account contractual thresholds

 

$

34,710

 

Additional collateral without contractual thresholds

 

 

67,038

 

 

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Energy Commodity Risk

Our energy commodity risks have not materially changed during the six months ended June 30, 2020, except as discussed below and the COVID-19 related risks. See the 2019 Form 10-K. The following table presents energy commodity derivative fair values as a net asset or (liability) as of June 30, 2020 that are expected to settle in each respective year (dollars in thousands). There are no expected deliveries of energy commodity derivatives after 2023.

 

 

 

Purchases

 

 

Sales

 

 

 

Electric Derivatives

 

 

Gas Derivatives

 

 

Electric Derivatives

 

 

Gas Derivatives

 

Year

 

Physical (1)

 

 

Financial (1)

 

 

Physical (1)

 

 

Financial (1)

 

 

Physical (1)

 

 

Financial (1)

 

 

Physical (1)

 

 

Financial (1)

 

Remainder 2020

 

$

100

 

 

$

(627

)

 

$

(293

)

 

$

6,131

 

 

$

15

 

 

$

1,205

 

 

$

(952

)

 

$

(6,163

)

2021

 

 

 

 

 

(79

)

 

 

78

 

 

 

4,168

 

 

 

 

 

 

1,228

 

 

 

(1,634

)

 

 

(2,984

)

2022

 

 

 

 

 

 

 

 

143

 

 

 

692

 

 

 

 

 

 

 

 

 

 

 

 

(173

)

2023

 

 

 

 

 

 

 

 

 

 

 

(16

)

 

 

 

 

 

 

 

 

 

 

 

 

 

The following table presents energy commodity derivative fair values as a net asset or (liability) as of December 31, 2019 that are expected to be delivered in each respective year (dollars in thousands). There are no expected deliveries of energy commodity derivatives after 2022.

 

 

 

Purchases

 

 

Sales

 

 

 

Electric Derivatives

 

 

Gas Derivatives

 

 

Electric Derivatives

��

 

Gas Derivatives

 

Year

 

Physical (1)

 

 

Financial (1)

 

 

Physical (1)

 

 

Financial (1)

 

 

Physical (1)

 

 

Financial (1)

 

 

Physical (1)

 

 

Financial (1)

 

2020

 

$

19

 

 

$

2,063

 

 

$

(895

)

 

$

10,929

 

 

$

(422

)

 

$

(7,448

)

 

$

(1,634

)

 

$

(8,922

)

2021

 

 

 

 

 

 

 

 

15

 

 

 

2,666

 

 

 

 

 

 

(26

)

 

 

(1,187

)

 

 

(1,941

)

2022

 

 

 

 

 

 

 

 

35

 

 

 

180

 

 

 

 

 

 

 

 

 

 

 

 

(5

)

 

(1)

Physical transactions represent commodity transactions in which we will take or make delivery of either electricity or natural gas; financial transactions represent derivative instruments with delivery of cash in the amount of the benefit or cost but with no physical delivery of the commodity, such as futures, swap derivatives, options, or forward contracts.

The above electric and natural gas derivative contracts will be included in either power supply costs or natural gas supply costs during the period they are delivered and will be included in the various deferral and recovery mechanisms (ERM, PCA, and PGAs), or in the general rate case process, and are expected to eventually be collected through retail rates from customers.

Item 3. Quantitative and Qualitative Disclosures about Market Risk

The information required by this item is set forth in the Enterprise Risk Management section of "Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations" and is incorporated herein by reference.

Item 4. Controls and Procedures

Conclusion Regarding the Effectiveness of Disclosure Controls and Procedures

The Company has disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Securities Exchange Act of 1934, as amended) (Act) that are designed to ensure that information required to be disclosed in the reports it files or submits under the Act is recorded, processed, summarized and reported on a timely basis. Disclosure controls and procedures include, without limitation, controls and procedures designed to ensure that information required to be disclosed by the Company in the reports that it files or submits under the Act is accumulated and communicated to the Company’s management, including its principal executive and principal financial officers, as appropriate, to allow timely decisions regarding required disclosure. With the participation of the Company’s principal executive officer and principal financial officer, the Company's management evaluated its disclosure controls and

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procedures as of the end of the period covered by this report. There are inherent limitations to the effectiveness of any system of disclosure controls and procedures, including the possibility of human error and the circumvention or overriding of the controls and procedures. Accordingly, even effective disclosure controls and procedures can only provide reasonable assurance of achieving their control objectives. Based upon this evaluation, the Company’s principal executive officer and principal financial officer have concluded that the Company’s disclosure controls and procedures are effective at a reasonable assurance level as of June 30, 2020.

There have been no changes in the Company's internal control over financial reporting that occurred during the second quarter of 2020 that have materially affected, or are reasonably likely to materially affect, the Company's internal control over financial reporting.

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PART II. Other Information

See “Note 15 of Notes to Condensed Consolidated Financial Statements” in “Part I. Financial Information Item 1. Condensed Consolidated Financial Statements.”

Item 1A. Risk Factors

Refer to the 2019 Form 10-K for disclosure of risk factors that could have a significant impact on our results of operations, financial condition or cash flows and could cause actual results or outcomes to differ materially from those discussed in our reports filed with the SEC (including this Quarterly Report on Form 10-Q), and elsewhere. These risk factors have not materially changed from the disclosures provided in the 2019 Form 10-K with the exception of the following:

The COVID 19 global pandemic is disrupting our business and could have a negative effect on our results of operations, financial condition and cash flows.

The COVID-19 global pandemic is currently impacting all aspects of our business, as well as the global, national and local economy. We cannot predict the full extent to which COVID-19 will impact our operations, results of operations, cash flows, financial condition or capital resources. It is possible that the continued spread of COVID-19 and efforts to contain the virus will continue to cause an economic slowdown and possibly a recession, resulting in significant disruptions in various public, commercial or industrial activities and causing employee absences which could interfere with operation and maintenance of the Company’s facilities. Any of these circumstances could adversely affect our operations, results of operations, financial condition and cash flows in the following ways, including, but not limited to:

 

A decrease in customer demand and revenues due to a reduction in economic activity and possibly a recession,

 

An increase in operating expenses, including bad debt expense due to our customers’ inability to pay amounts due to us,

 

A negative impact on the ability of suppliers, vendors or contractors to perform, which could increase costs and delay capital projects,

 

Regulatory commissions may not approve our requests to defer and recover increased expenses,

 

Delays in regulatory filings and the regulatory approval process, which could impact our ability to timely recover our operating expenses and costs associated with investments in utility assets,

 

An increase in cyber and technology risks, including the impact on internal controls, due to a significant number of employees working remotely,

 

A decrease in the fair value of pension plan assets or an increase in the pension liability, which could increase future pension plan funding requirements,

 

A decrease in the fair value of non-utility investments, which could result in losses or impairment,

 

A decrease in net operating cash inflows, which could negatively impact our liquidity and limit our ability to fund capital expenditures, dividends, and other contractual commitments,

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Disruption, weakness and volatility in the financial markets, which could increase our costs to fund capital requirements,

 

To the extent that access to the capital markets is adversely affected, we may need to consider alternative sources of funding for operations and for working capital, any of which could increase our cost of capital.

 

We cannot predict the duration and severity of the COVID-19 global pandemic. The longer and more severe the economic restrictions and business disruption is, the greater the impact on our operations, results of operations, financial condition and cash flows will be.

In addition to these risk factors, see also “Forward-Looking Statements” for additional factors which could have a significant impact on our operations, results of operations, financial condition or cash flows and could cause actual results to differ materially from those anticipated in such statements.

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Item 6. Exhibits

 

15

 

Letter Re: Unaudited Interim Financial Information (1)

 

 

 

31.1

 

Certification of Chief Executive Officer (Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002) (1)

 

 

 

31.2

 

Certification of Chief Financial Officer (Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002) (1)

 

 

 

32

 

Certification of Corporate Officers (Furnished Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002) (2)

 

 

 

101.INS

 

Inline XBRL Instance Document. The instance document does not appear in the interactive data file because its inline XBRL tags are embedded within the inline XBRL document.

101.SCH

 

Inline XBRL Taxonomy Extension Schema Document

101.CAL

 

Inline XBRL Taxonomy Extension Calculation Linkbase Document

101.LAB

 

Inline XBRL Taxonomy Extension Label Linkbase Document

101.PRE

 

Inline XBRL Taxonomy Extension Presentation Linkbase Document

101.DEF

 

Inline XBRL Taxonomy Extension Definition Linkbase Document

104

 

Cover page formatted as Inline XBRL and contained in Exhibit 101.

 

 

 

(1)

 

Filed herewith.

(2)

 

Furnished herewith.

 

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SIGNATURE

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

 

 

 

 

AVISTA CORPORATION

 

 

 

(Registrant)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Date:

August 4, 2020

 

/s/    Mark T. Thies

 

 

 

Mark T. Thies

 

 

 

Executive Vice President,

Chief Financial Officer, and Treasurer

(Principal Financial Officer)

 

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