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Plan Amended 11-12-2020
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12-17-20
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(Exact name of registrant as specified in its charter)
iDelaware
i30-1133956
(State
or other jurisdiction of
incorporation or organization)
(I.R.S. Employer Identification No.)
i1200 West Century Avenue
iP.O.
Box 5650
iBismarck, iNorth Dakotai58506-5650
(Address of principal executive offices)
(Zip Code)
(i701) i530-1000
(Registrant's telephone number, including area code)
Securities registered pursuant to Section 12(b) of the Act:
Title
of each class
Trading symbol(s)
Name of each exchange on which registered
iCommon Stock, par value $1.00 per share
iMDU
iNew
York Stock Exchange
Securities registered pursuant to Section 12(g) of the Act: None
Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act. iYes☒ No ☐.
Indicate by check mark if the
registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the Act. Yes ☐iNo☒.
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. iYes☒ 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 such files). iYes☒ No ☐.
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a 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.
iLarge accelerated filer
☒
Accelerated filer
☐
Non-accelerated
filer
☐
Smaller reporting company
i☐
Emerging growth company
i☐
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 has filed a report on and attestation to its management's assessment of the effectiveness of its internal control over financial reporting under Section 404(b) of the Sarbanes-Oxley Act (15 U.S.C. 7262(b)) by the registered public accounting firm that prepared or issued its audit report. i☒
Indicate
by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Act). Yes i☐ No ☒.
State the aggregate market value of the voting common stock held by non-affiliates of the registrant as of June 30, 2020: $i4,447,584,104.
The following abbreviations and acronyms used in this Form 10-K are defined below:
Abbreviation or Acronym
AFUDC
Allowance
for funds used during construction
Army Corps
U.S. Army Corps of Engineers
ASC
FASB Accounting Standards Codification
ASU
FASB Accounting Standards Update
Audit Committee
Audit Committee of the board of directors of the Company
Bcf
Billion cubic feet
Big
Stone Station
475-MW coal-fired electric generating facility near Big Stone City, South Dakota (22.7 percent ownership)
Brazilian Transmission Lines
Company's former investment in companies owning three electric transmission lines in Brazil
BSSE
345-kilovolt transmission line from Ellendale, North Dakota, to Big Stone City, South Dakota (50 percent ownership)
Btu
British thermal unit
CARES Act
United States Coronavirus Aid, Relief, and Economic
Security Act
Cascade
Cascade Natural Gas Corporation, an indirect wholly owned subsidiary of MDU Energy Capital
CDC
Centers for Disease Control and Prevention
Centennial
Centennial Energy Holdings, Inc., a direct wholly owned subsidiary of the Company
Centennial Capital
Centennial Holdings Capital LLC, a direct wholly owned subsidiary of Centennial
Centennial's
Consolidated EBITDA
Centennial's consolidated net income from continuing operations plus the related interest expense, taxes, depreciation, depletion, amortization of intangibles and any non-cash charge relating to asset impairment for the preceding 12-month period
Centennial Resources
Centennial Energy Resources LLC, a direct wholly owned subsidiary of Centennial
CERCLA
Comprehensive Environmental Response, Compensation and Liability Act
Clean Air Act
Federal Clean Air Act
Clean Water Act
Federal
Clean Water Act
Company
MDU Resources Group, Inc. (formerly known as MDUR Newco), which, as the context requires, refers to the previous MDU Resources Group, Inc. prior to January 1, 2019, and the new holding company of the same name after January 1, 2019
COVID-19
Coronavirus disease 2019
Coyote Creek
Coyote Creek Mining Company, LLC, a subsidiary of The North American Coal Corporation
Coyote Station
427-MW
coal-fired electric generating facility near Beulah, North Dakota (25 percent ownership)
CyROC
Cyber Risk Oversight Committee
Dakota Prairie Refining
Dakota Prairie Refining, LLC, a limited liability company previously owned by WBI Energy and Calumet Specialty Products Partners, L.P. (previously included in the Company's refining segment)
dk
Decatherm
Dodd-Frank Act
Dodd-Frank Wall Street Reform and Consumer
Protection Act
EBITDA
Earnings before interest, taxes, depreciation, depletion and amortization
EIN
Employer Identification Number
EPA
United States Environmental Protection Agency
ERISA
Employee Retirement Income Security Act of 1974
ESA
Endangered Species Act
Exchange Act
Securities
Exchange Act of 1934, as amended
FASB
Financial Accounting Standards Board
FERC
Federal Energy Regulatory Commission
Fidelity
Fidelity Exploration & Production Company, a direct wholly owned subsidiary of WBI Holdings (previously referred to as the Company's exploration and production segment)
FIP
Funding improvement plan
GAAP
Accounting
principles generally accepted in the United States of America
GHG
Greenhouse gas
Great Plains
Great Plains Natural Gas Co., a public utility division of the Company prior to the closing of the Holding Company Reorganization and a public utility division of Montana-Dakota as of January 1, 2019
GVTC
Generation Verification Test Capacity
4 MDU
Resources Group, Inc. Form 10-K
Definitions
Holding Company Reorganization
The internal holding company reorganization completed on January 1, 2019, pursuant to the agreement and plan of merger, dated as of December
31, 2018, by and among Montana-Dakota, the Company and MDUR Newco Sub, which resulted in the Company becoming a holding company and owning all of the outstanding capital stock of Montana-Dakota.
IBEW
International Brotherhood of Electrical Workers
ICWU
International Chemical Workers Union
Intermountain
Intermountain Gas Company, an indirect wholly owned subsidiary of MDU Energy Capital
IPUC
Idaho
Public Utilities Commission
Item 8
Financial Statements and Supplementary Data
Knife River
Knife River Corporation, a direct wholly owned subsidiary of Centennial
Knife River - Northwest
Knife River Corporation - Northwest, an indirect wholly owned subsidiary of Knife River
K-Plan
Company's 401(k) Retirement Plan
kW
Kilowatts
kWh
Kilowatt-hour
LIBOR
London
Inter-bank Offered Rate
LWG
Lower Willamette Group
MD&A
Management's Discussion and Analysis of Financial Condition and Results of Operations
Mdk
Thousand dk
MDU Construction Services
MDU Construction Services Group, Inc., a direct wholly owned subsidiary of Centennial
MDU Energy Capital
MDU Energy Capital, LLC, a direct wholly owned subsidiary of the
Company
MDUR Newco
MDUR Newco, Inc., a public holding company created by implementing the Holding Company Reorganization, now known as the Company
MDUR Newco Sub
MDUR Newco Sub, Inc., a direct, wholly owned subsidiary of MDUR Newco, which was merged with and into Montana-Dakota in the Holding Company Reorganization
MEPP
Multiemployer pension plan
MISO
Midcontinent Independent System Operator,
Inc.
MMBtu
Million Btu
MMcf
Million cubic feet
MMdk
Million dk
MNPUC
Minnesota Public Utilities Commission
Montana-Dakota
Montana-Dakota Utilities Co. (formerly known as MDU Resources Group, Inc.), a public utility division of the Company prior to the closing of the Holding Company Reorganization
and a direct wholly owned subsidiary of MDU Energy Capital as of January 1, 2019
MPPAA
Multiemployer Pension Plan Amendments Act of 1980
MTDEQ
Montana Department of Environmental Quality
MTPSC
Montana Public Service Commission
MW
Megawatt
NDDEQ
North Dakota Department of Environmental Quality
NDPSC
North
Dakota Public Service Commission
NERC
North American Electric Reliability Corporation
Non-GAAP
Not in accordance with GAAP
Oil
Includes crude oil and condensate
OPUC
Oregon Public Utility Commission
PCBs
Polychlorinated biphenyls
Proxy Statement
Company's
2021 Proxy Statement to be filed no later than April 30, 2021
PRP
Potentially Responsible Party
RCRA
Resource Conservation and Recovery Act
RNG
Renewable Natural Gas
ROD
Record of Decision
RP
Rehabilitation plan
SDPUC
South
Dakota Public Utilities Commission
SEC
United States Securities and Exchange Commission
Securities Act
Securities Act of 1933, as amended
Securities Act Industry Guide 7
Description of Property by Issuers Engaged or to be Engaged in Significant Mining Operations
Sheridan System
A separate electric system owned by Montana-Dakota
MDU
Resources Group, Inc. Form 10-K 5
Definitions
SOFR
Secured Overnight Financing Rate
TCJA
Tax Cuts and Jobs Act
UA
United
Association of Journeyman and Apprentices of the Plumbing and Pipefitting Industry of the United States and Canada
VIE
Variable interest entity
Washington DOE
Washington State Department of Ecology
WBI Energy
WBI Energy, Inc., a direct wholly owned subsidiary of WBI Holdings
WBI Energy Transmission
WBI Energy Transmission, Inc., an indirect wholly owned subsidiary of WBI Holdings
WBI Holdings
WBI
Holdings, Inc., a direct wholly owned subsidiary of Centennial
WUTC
Washington Utilities and Transportation Commission
Wygen III
100-MW coal-fired electric generating facility near Gillette, Wyoming (25 percent ownership)
WYPSC
Wyoming Public Service Commission
ZRCs
Zonal resource credits - a MW of demand equivalent assigned to generators by MISO for meeting system reliability requirements
6 MDU
Resources Group, Inc. Form 10-K
Part I
Forward-Looking Statements
This Form 10-K contains forward-looking statements within the meaning of Section 21E of the Exchange Act. Forward-looking statements are all statements other than statements of historical fact, including without limitation
those statements that are identified by the words "anticipates,""estimates,""expects,""intends,""plans,""predicts" and similar expressions, and include statements concerning plans, objectives, goals, strategies, future events or performance, and underlying assumptions (many of which are based, in turn, upon further assumptions) and other statements that are other than statements of historical facts. From time to time, the Company may publish or otherwise make available forward-looking statements of this nature, including statements contained within Item 7 - MD&A - Business Segment Financial and Operating Data.
Forward-looking statements involve risks and uncertainties, which could cause actual results or outcomes to differ materially from those expressed. The
Company's expectations, beliefs and projections are expressed in good faith and are believed by the Company to have a reasonable basis, including without limitation, the impact of COVID-19 on the Company's business, management's examination of historical operating trends, data contained in the Company's records and other data available from third parties. Nonetheless, the Company's expectations, beliefs or projections may not be achieved or accomplished.
Any forward-looking statement contained in this document speaks only as of the date on which the statement is made, and the
Company undertakes no obligation to update any forward-looking statement or statements to reflect events or circumstances that occur after the date on which the statement is made or to reflect the occurrence of unanticipated events. New factors emerge from time to time and it is not possible for management to predict all of the factors, nor can it assess the effect of each factor on the Company's business or the extent to which any factor, or combination of factors, may cause actual results to differ materially from those contained in any forward-looking statement. All forward-looking statements, whether written or oral and whether made by or on behalf of the Company, are expressly qualified by the risk factors and cautionary statements in this Form 10-K, including statements contained within Item 1A
- Risk Factors.
Items 1 and 2. Business and Properties
General
The Company is a regulated energy delivery and construction materials and services business. Its principal executive offices are located at 1200 West Century Avenue, P.O. Box 5650, Bismarck, North Dakota58506-5650,
telephone (701) 530-1000.
Montana-Dakota was incorporated under the state laws of Delaware in 1924. The Company was incorporated under the state laws of Delaware in 2018. On January 2, 2019, the Company announced the completion of the Holding Company Reorganization, which resulted in Montana-Dakota becoming a subsidiary of the Company. Immediately after consummation of the Holding Company Reorganization, the Company had, on a consolidated
basis, the same assets, businesses and operations as immediately prior to the consummation of the Holding Company Reorganization.
The Company's strategy is to deliver superior value with a two-platform model, regulated energy delivery and construction materials and services businesses, while also pursuing organic growth opportunities and using a disciplined approach to strategic acquisitions of well-managed companies and properties.
The Company focuses on infrastructure and is Building a Strong America® by providing essential products and services through its regulated energy delivery platform and its construction materials and services platform, which are both comprised of different operating segments. Most of these segments
experience seasonality related to the industries in which they operate. The two-platform approach helps balance this seasonality and the risk associated with each type of industry. Through its regulated energy delivery platform, the Company generates, transmits and distributes electricity and provides natural gas distribution, transportation and storage services. These businesses are regulated by state public service commissions and/or the FERC. The construction materials and services platform provides construction services to a variety of industries, including commercial, industrial and governmental customers, and provides construction materials through aggregate mining and marketing of related products, such as ready-mixed concrete, asphalt and asphalt oil.
The Company
is organized into five reportable business segments. These business segments include: electric, natural gas distribution, pipeline, construction materials and contracting, and construction services. The Company's business segments are determined based on the Company's method of internal reporting, which generally segregates the strategic business units due to differences in products, services and regulation. The internal reporting of these segments is defined based on the reporting and review process used by the Company's chief executive officer.
The Company, through its wholly owned subsidiary, MDU
Energy Capital, owns Montana-Dakota, Cascade and Intermountain. The electric segment is comprised of Montana-Dakota while the natural gas distribution segment is comprised of Montana-Dakota, Cascade and Intermountain.
The Company, through its wholly owned subsidiary, Centennial, owns WBI Holdings, Knife River, MDU Construction Services and Centennial Capital. WBI Holdings is the pipeline segment, Knife River is the construction materials and contracting segment, MDU Construction Services is the construction services segment, and Centennial Capital is reflected in the Other category.
MDU Resources Group, Inc.
Form 10-K 7
Part I
The financial results and data applicable to each of the Company's business segments, as well as their financing requirements, are set forth in Item 7 - MD&A and Item 8 - Note 17.
The Company's material properties, which are of varying ages and are of different construction types, are generally in good condition, are well maintained and are generally suitable and adequate
for the purposes for which they are used.
Human Capital Management At the core of Building a Strong America® is building a strong team of employees with a focus on safety and a commitment to diversity and inclusion. The Company's team consisted of 12,994 employees located in 40 states plus Washington D.C. as of December 31, 2020. The number of employees fluctuates during the year due to the seasonality and the number and size of construction projects. During 2020, the number of employees peaked at 15,668. Employees as of December 31, 2020, were as follows:
Company
Number
of employees
MDU Resources Group, Inc.
250
MDU Energy Capital
1,592
WBI Holdings
323
Knife River
3,582
MDU Construction Services
7,247
Total employees
12,994
Many
of the Company's employees are represented by collective-bargaining agreements. The majority of the collective-bargaining agreements contain provisions that prohibit work stoppages or strikes and provide for binding arbitration dispute resolution in the event of an extended disagreement. The following information is as of December 31, 2020.
SafetyThe Company is committed to safety and health in the workplace and subscribes to the principle that all injuries can be prevented. To ensure safe work environments, the Company provides training, adequate resources and appropriate follow-up on any unsafe conditions or actions.
To facilitate a strong safety culture, the Company established its Safety Leadership
Council which is charged with receiving and reviewing information for the identification and adoption of best practices in the prevention of occupationally induced injuries and illness, as well as monitoring the effectiveness of the Company's safety and environmental health programs.
In addition to the Safety Leadership Council, the Company has policies and training that support safety in the workplace including training on safety matters through classroom and toolbox meetings on job sites. The Company utilizes safety compliance in the evaluation of employees, which includes management, and recognizes employee safety through safety award programs. Accident and safety statistical information
is gathered for each of the business segments and regularly reported to management and the board of directors.
In response to COVID-19, the Company established a task force to monitor developments related to the pandemic and implemented procedures to protect employees. The Company adopted recommended practices from the CDC and is following directives of each state and local jurisdiction in which the Company operates. Some of these practices include, among other things, a daily COVID-19 self-assessment to access Company facilities; social distancing; telecommuting; virtual meetings; designated entrances, exits and stairwells; restricted business travel; and increased access to personal
protective equipment.
Building People Employees are hired having the skills, abilities and motivation to achieve the results needed for their jobs. Each job is important and part of a coordinated team effort to accomplish the organization's objectives. The Company provides opportunities for advancement through job mobility, succession planning and promotions both within and between business segments.
The Company uses a variety of recruiting sources depending on the position, market and job requirements. All open positions across the Company's businesses are posted on the
Company's websitewww.jobs.mdu.com. Other sources for recruiting employees include team member referrals, union workforce, direct recruitment and various forms of advertising, including social media. The Company also uses internship programs to introduce
8 MDU Resources Group, Inc. Form 10-K
Part
I
individuals to the Company's business operations and provide a possible source of future employees. In markets where labor availability is tight, the Company uses telecommuting, guaranteed hours, flexible schedules and work arrangements to fill open positions.
To attract and retain employees, the Company offers:
•Competitive salaries and wages based on the labor markets in which it operates.
•Employee
growth through training in the form of technical, professional and leadership programs. The Company also provides formal and informal mentoring and job shadowing programs to assist employees in their job and career goals.
•Incentive compensation opportunities based on the Company's performance.
•Comprehensive benefits including vacation, sick leave, health and wellness programs, retirement plans and discount programs.
Diversity and Inclusion To further its corporate vision, the Company is committed to an inclusive environment
that respects the differences and embraces the strengths of its diverse employees. Each business segment has an appointed diversity officer who serves as a conduit for diversity-related issues by providing a voice to all employees. The Company has three strategic goals related to diversity:
•Increase productivity and profitability through the creation of a work environment which values all perspectives and methods of accomplishing work.
•Enhance collaboration efforts through cooperation and sharing of best practices to create new ways of meeting employee, customer and shareholder needs.
•Maintain a culture of integrity, respect and safety by ensuring employees understand these essential
values which are part of the Company's vision statement.
The Company provides training and has policies which speak to diversity and inclusion. Training for employees on diversity and inclusion topics include equal employment opportunity, workplace harassment, respect and unconscious bias. In 2020, the Company implemented a telecommuting policy to allow certain employees to work from home or other offsite locations. The flexibility of the policy may expand the potential applicant pool for job openings beyond the Company's traditional geographic footprint.
The
Company also promotes its strategic diversity goals through the following special recognition awards:
•The Einstein award recognizes the best process improvement ideas that contribute in a measurable way to improving the Company's bottom line and are vital to the Company's success.
•The Community Spirit award recognizes employees who are actively involved in their community.
•The Summit award recognizes employees who make the Company a better place to work.
•The
Environmental Integrity award recognizes an employee program, project or activity that reflects the Company's environmental policy and philosophy.
•The Hero Award recognizes employees who go above and beyond the call of duty to save another's life.
Governmental Matters The operations of the Company and certain of its subsidiaries are subject to laws and regulations relating to air, water and solid waste pollution control; state facility-siting regulations; zoning and planning regulations of certain state and local authorities; federal and state health and safety regulations; and state
hazard communication standards. The Company believes it is in substantial compliance with these regulations, except as to what may be ultimately determined with regard to items discussed in Environmental matters in Item 8 - Note 21. There are no pending CERCLA actions for any of the Company's material properties. However, the Company is involved in certain claims relating to the Portland, Oregon, Harbor Superfund Site and the Bremerton Gasworks Superfund Site. For more information on the Company's environmental matters, see Item 8 - Note 21.
The
Company produces GHG emissions primarily from its fossil fuel electric generating facilities, as well as from natural gas pipeline and storage systems, and operations of equipment and fleet vehicles. GHG emissions also result from customer use of natural gas for heating and other uses. As interest in reductions in GHG emissions has grown, the Company has developed renewable generation with lower or no GHG emissions. Governmental legislation and regulatory initiatives regarding environmental and energy policy are continuously evolving and could negatively impact the Company's operations and financial results. Until legislation and regulation are finalized, the impact of these measures cannot be accurately predicted. The Company
will continue to monitor legislative and regulatory activity related to environmental and energy policy initiatives. Disclosure regarding specific environmental matters applicable to each of the Company's businesses is set forth under each business description later. In addition, for a discussion of the Company's risks related to environmental laws and regulations, see Item 1A - Risk Factors.
Technology The Company uses technology in substantially all aspects of its business operations and requires uninterrupted operation of information technology systems and network infrastructure. These systems may be vulnerable to failures or unauthorized access. The
Company has policies, procedures and processes designed to strengthen and protect these systems, which include the Company’s enterprise information technology and operation technology groups continually evaluating new tools and techniques to reduce the risk of a cyber breach.
The Company created CyROC to oversee its approach to cybersecurity. CyROC is responsible for supplying management and the Audit Committee with analyses, appraisals, recommendations and pertinent information concerning cyber defense of the Company’s electronic information and
MDU
Resources Group, Inc. Form 10-K 9
Part I
information technology systems. A quarterly cybersecurity report is provided to the Audit Committee. For a discussion of the Company's risks related to cybersecurity, see Item 1A - Risk Factors.
Available Information This annual report on Form 10-K, the Company's quarterly reports on Form 10-Q and current
reports on Form 8-K, and any amendments to those reports filed or furnished pursuant to Section 13(a) or 15(d) of the Exchange Act are available free of charge through the Company's website as soon as reasonably practicable after the Company has electronically filed such reports with, or furnished such reports to, the SEC. The Company's website address is www.mdu.com. The information
available on the Company's website is not part of this annual report on Form 10-K. The SEC also maintains a website where the Company's filings can be obtained free of charge at www.SEC.gov.
Electric
GeneralThe Company's electric segment is operated through
its wholly owned subsidiary, Montana-Dakota. Montana-Dakota provides electric service at retail, serving residential, commercial, industrial and municipal customers in 185 communities and adjacent rural areas in Montana, North Dakota, South Dakota and Wyoming. For more information on the retail customer classes served, see the table below. The material properties owned by Montana-Dakota for use in its electric operations include interests in 16 electric generating units at 11 facilities and two small portable diesel generators, as further described under System Supply, System Demand and Competition, approximately 3,400 and 4,900 miles of transmission and distribution lines, respectively, and 81 transmission and 298 distribution substations. Montana-Dakota has obtained and holds, or is in the process of renewing, valid and existing franchises authorizing it to conduct its electric operations in all of the municipalities it serves where such franchises are required. Montana-Dakota
intends to protect its service area and seek renewal of all expiring franchises. At December 31, 2020, Montana-Dakota's net electric plant investment was $1.5 billion and its rate base was $1.3 billion.
The retail customers served and respective revenues by class for the electric business were as follows:
2020
2019
2018
Customers Served
Revenues
Customers Served
Revenues
Customers Served
Revenues
(Dollars
in thousands)
Residential
118,893
$
122,545
118,563
$
125,614
118,426
$
126,173
Commercial
23,050
131,207
22,948
142,062
22,756
141,961
Industrial
230
36,736
234
37,790
236
36,081
Other
1,609
6,601
1,601
7,454
1,604
7,882
143,782
$
297,089
143,346
$
312,920
143,022
$
312,097
Other
electric revenues, which are largely transmission-related revenues, for Montana-Dakota were $34.9 million, $38.8 million and $23.0 million for the years ended December 31, 2020, 2019 and 2018, respectively.
The percentage of electric retail revenues by jurisdiction was as follows:
2020
2019
2018
North
Dakota
64
%
65
%
66
%
Montana
22
%
22
%
20
%
Wyoming
9
%
8
%
9
%
South
Dakota
5
%
5
%
5
%
Retail electric rates, service, accounting and certain security issuances are subject to regulation by the MTPSC, NDPSC, SDPUC and WYPSC. The interstate transmission and wholesale electric power operations of Montana-Dakota are also subject to regulation by the FERC under provisions of the Federal Power Act, as are interconnections with other utilities and power generators, the issuance of certain securities, accounting, cybersecurity and other matters.
Through MISO, Montana-Dakota has access to wholesale energy, ancillary services and capacity
markets for its interconnected system. MISO is a regional transmission organization responsible for operational control of the transmission systems of its members. MISO provides security center operations, tariff administration and operates day-ahead and real-time energy markets, ancillary services and capacity markets. As a member of MISO, Montana-Dakota's generation is sold into the MISO energy market and its energy needs are purchased from that market.
System Supply, System Demand and CompetitionThrough an interconnected electric system, Montana-Dakota serves markets in portions of North Dakota, Montana and South Dakota. These markets are highly seasonal and sales volumes depend largely on the weather. Additionally, the average customer consumption has tended to decline due to increases in energy efficient lighting and appliances being installed. The interconnected system consists
of 15 electric generating units at 10 facilities and two small portable diesel generators, which have an aggregate nameplate rating attributable to Montana-Dakota's interest of 750,318 kW and total net ZRCs of 512.3 in 2020. For 2020, Montana-Dakota's total ZRCs, including its firm purchase power contracts, were 553.2. Montana-Dakota's planning reserve margin requirement within MISO was 531.4 ZRCs for 2020. The maximum electric peak demand experienced to date attributable to Montana-Dakota's sales to retail customers on the interconnected system was 611,542 kW in August 2015. Montana-Dakota's latest forecast for its interconnected system indicates that its annual peak will continue to occur
10 MDU
Resources Group, Inc. Form 10-K
Part I
during the summer. Montana-Dakota's interconnected system electric generating capability includes five steam-turbine generating units at four facilities using coal for fuel, four natural gas combustion turbine units at three facilities, three wind electric generating facilities, two natural gas-fired reciprocating internal combustion engines at one facility, a heat recovery electric generating facility and two small portable diesel generators.
Additional energy is purchased as needed, or in lieu
of generation if more economical, from the MISO market, and in 2020, Montana-Dakota purchased approximately 25 percent of its net kWh needs for its interconnected system through the MISO market.
Approximately 30 percent of the electricity delivered to customers from Montana-Dakota's owned generation in 2020 was from renewable resources. Although Montana-Dakota's generation resource capacity has increased to serve the needs of its customers, the carbon dioxide emission intensity of its electric generation resource fleet has been reduced by approximately 28 percent since 2005 through the addition of renewable generation and MISO market purchases. Montana-Dakota's carbon dioxide emissions are expected to continue to decline through the retirement of aging coal-fired electric generating units.
Through the Sheridan System, Montana-Dakota serves Sheridan, Wyoming, and neighboring communities.
The maximum peak demand experienced to date attributable to Montana-Dakota sales to retail customers on that system was approximately 64,129 kW in July 2020. Montana-Dakota has a power supply contract with Black Hills Power, Inc. to purchase up to 49,000 kW of capacity annually through December 31, 2023. Wygen III also serves a portion of the needs of Montana-Dakota's Sheridan-area customers.
The following table sets forth details applicable to the Company's electric generating stations:
Generating
Station
Type
Nameplate Rating (kW)
2020 ZRCs
(a)
2020 Net Generation (kWh in thousands)
Interconnected System:
North Dakota:
Coyote
(b)
Steam
103,647
92.7
552,839
Heskett
Steam
86,000
87.9
469,765
Heskett
Combustion Turbine
89,038
77.9
1,331
Glen
Ullin
Heat Recovery
7,500
4.8
29,813
Cedar Hills
Wind
19,500
4.0
55,889
Thunder Spirit
Wind
155,500
24.2
600,626
South
Dakota:
Big Stone (b)
Steam
94,111
105.7
394,021
Montana:
Lewis & Clark
Steam
44,000
—
232,433
Lewis
& Clark
Reciprocating Internal Combustion Engine
18,700
17.6
1,613
Glendive
Combustion Turbine
75,522
67.6
853
Miles City
Combustion Turbine
23,150
21.2
349
Diamond
Willow
Wind
30,000
5.5
98,781
Diesel Units
Oil
3,650
3.2
10
750,318
512.3
2,438,323
Sheridan
System:
Wyoming:
Wygen III (b)
Steam
28,000
N/A
209,423
778,318
512.3
2,647,746
(a) Interconnected
system only. MISO requires generators to obtain their summer capability through the GVTC. The GVTC is then converted to ZRCs by applying each generator's forced outage factor against its GVTC. Wind generator's ZRCs are calculated based on a wind capacity study performed annually by MISO. ZRCs are used to meet supply obligations within MISO.
(b) Reflects Montana-Dakota's ownership interest.
Virtually all of the current fuel requirements of the Lewis & Clark and Heskett stations are met with coal supplied by wholly-owned subsidiaries of Westmoreland Mining LLC under contracts
that expire in March 2021 and December 2021, respectively. The Lewis & Clark and Heskett coal supply agreements provide for the purchase of coal necessary to supply the coal requirements of these stations at contracted pricing. Montana-Dakota estimates the Lewis & Clark coal requirement to be 60,000 tons through March 2021 and in the range of 400,000 to 425,000 tons per contract year for Heskett.
In February 2019, Montana-Dakota announced the retirement of three aging coal-fired electric generating units, Unit 1 at Lewis & Clark Station and Units 1 and 2 at Heskett Station. The retirements are expected to be completed in March 2021 for Lewis & Clark Station and early 2022 for Heskett Station. Montana-Dakota also announced the intent to construct a new 88-MW simple-cycle natural gas-fired combustion turbine peaking unit
at the existing Heskett Station.
MDU Resources Group, Inc. Form 10-K 11
Part I
The owners of Coyote Station, including Montana-Dakota, have a contract with Coyote Creek for coal supply to the Coyote Station that expires December 2040. Montana-Dakota estimates
the Coyote Station coal supply agreement to be approximately 1.5 million tons per contract year. For more information, see Item 8 - Note 21.
The owners of Big Stone Station, including Montana-Dakota, have a coal supply agreement with Peabody COALSALES, LLC to meet all of the Big Stone Station's fuel requirements through 2022. Montana-Dakota estimates the Big Stone Station coal supply agreement to be approximately 1.5 million tons per contract year.
Montana-Dakota has a coal supply agreement with Wyodak Resources Development Corp., to supply the coal requirements of Wygen III at contracted pricing through June 1, 2060. Montana-Dakota estimates the maximum annual coal consumption of the facility to be 594,000 tons.
The
average cost of coal purchased, including freight, at Montana-Dakota's electric generating stations (including the Big Stone, Coyote and Wygen III stations) was as follows:
Montana-Dakota expects that it has secured adequate capacity available through existing baseload generating stations, renewable generation, turbine peaking stations, demand reduction programs and firm contracts to meet the peak customer demand requirements of its customers through 2025. Future capacity needs are expected to be met by constructing new generation resources or acquiring additional capacity through power purchase contracts
or the MISO capacity auction.
Montana-Dakota has major interconnections with its neighboring utilities and considers these interconnections adequate for coordinated planning, emergency assistance, exchange of capacity and energy and power supply reliability.
Montana-Dakota is subject to competition resulting from customer demands, technological advances and other factors in certain areas, from rural electric cooperatives, on-site generators, co-generators and municipally owned systems. In addition, competition in varying degrees exists between electricity and alternative forms of energy such as natural gas.
Regulatory Matters and Revenues Subject to RefundIn North Dakota, Montana, South Dakota and Wyoming, there are various recurring regulatory mechanisms with annual true-ups that can impact
Montana-Dakota's results of operations, which also reflect monthly increases or decreases in electric fuel and purchased power costs (including demand charges). Montana-Dakota is deferring those electric fuel and purchased power costs that are greater or less than amounts presently being recovered through its existing rate schedules. Examples of these recurring mechanisms include: monthly Fuel and Purchased Power Tracking Adjustments, a fuel adjustment clause and an annual Electric Power Supply Cost Adjustment. Such mechanisms generally provide that these deferred fuel and purchased power costs are recoverable or refundable through rate adjustments which are filed annually. Montana-Dakota's results of operations reflect 95 percent of the increases or decreases from the base purchased power costs and also reflect 85 percent of the increases or decreases from the base coal price, which is also recovered through the Electric Power Supply Cost Adjustment in Wyoming. For
more information on regulatory assets and liabilities, see Item 8 - Note 6.
All of Montana-Dakota's wind resources pertaining to electric operations in North Dakota are included in a renewable resource cost adjustment rider, including the North Dakota investment in the Thunder Spirit Wind project. Montana-Dakota also has a transmission tracker in North Dakota to recover transmission costs associated with MISO and the Southwest Power Pool, regional transmission organizations serving parts of Montana-Dakota's system, along with certain of the transmission investments not recovered through retail rates. The tracking mechanism has an annual true-up.
In South Dakota, Montana-Dakota recovers the South Dakota investment in the Thunder Spirit Wind project through an Infrastructure Rider tracking mechanism that is subject to an annual true-up. Montana-Dakota also has in place in South Dakota
a transmission tracker to recover transmission costs associated with MISO and the Southwest Power Pool, regional transmission organizations serving parts of Montana-Dakota's system, along with certain of the transmission investments not recovered through retail rates. This tracking mechanism also has an annual true-up.
In Montana, Montana-Dakota recovers in rates, through a tracking mechanism, its allocated share of Montana property-related taxes assessed to electric operations on an after-tax basis.
For more information on regulatory matters, see Item 8 - Note 20.
Environmental MattersMontana-Dakota's electric operations are subject to federal, state and local laws and regulations providing for air, water and solid waste pollution control; state facility-siting regulations; zoning and planning
regulations of certain state and local authorities; federal and state health and safety regulations; and state hazard communication standards. Montana-Dakota believes it is in substantial compliance with these regulations.
12 MDU Resources Group, Inc. Form 10-K
Part I
Montana-Dakota's electric generating facilities have Title V Operating Permits, under the Clean
Air Act, issued by the states in which they operate. Each of these permits has a five-year life. Near the expiration of these permits, renewal applications are submitted. Permits continue in force beyond the expiration date, provided the application for renewal is submitted by the required date, usually six months prior to expiration. The Title V Operating Permit renewal application for Coyote Station was submitted timely to the North Dakota Department of Health in September 2017, and the permit was issued on May 27, 2020. Wygen III is allowed to operate under the facility's construction permit until the Title V Operating Permit is issued by the Wyoming Department of Environmental Quality. The Title V Operating Permit application for Wygen III was submitted timely in January 2011, with the permit issuance date not specified at this time. The Title V Operating Permit renewal application for Heskett Station was submitted
timely in June 2019 to the NDDEQ and the permit was issued on February 4, 2020. The Title V Operating Permit renewal application for Lewis & Clark Station was submitted timely in December 2019 to the MTDEQ with the permit issuance date not specified at this time. The Title V Operating Permit renewal applications for Miles City and Glendive Combustion Turbine facilities were submitted timely in December 2020 to the MTDEQ with the permit issuance dates not specified at this time.
State water discharge permits issued under the requirements of the Clean Water Act are maintained for power production facilities on the Yellowstone and Missouri rivers. These permits also have five-year lives. Montana-Dakota renews these permits as necessary prior to expiration. Other permits held by these facilities may include an initial siting permit, which is typically a one-time, preconstruction
permit issued by the state; state permits to dispose of combustion by-products; state authorizations to withdraw water for operations; and Army Corps permits to construct water intake structures. Montana-Dakota's Army Corps permits grant one-time permission to construct and do not require renewal. Other permit terms vary and the permits are renewed as necessary.
Montana-Dakota's electric operations are very small-quantity generators of hazardous waste and subject only to minimum regulation under the RCRA. Montana-Dakota routinely handles PCBs from its electric operations in accordance with federal requirements. PCB storage areas are registered with the EPA as required.
Montana-Dakota incurred approximately $800,000 of environmental capital expenditures in 2020, mainly for an embankment stabilization project at Lewis & Clark Station and coal ash management projects for Lewis &
Clark Station and Coyote Station. Environmental capital expenditures are estimated to be $600,000, $3.9 million and $4.1 million in 2021, 2022 and 2023, respectively, for various environmental projects, including a coal ash impoundment closure project at Lewis & Clark Station and coal ash landfill closure project at Heskett Station. Montana-Dakota's capital and operational expenditures could also be affected by future environmental requirements, such as regional haze emissions reductions. For more information, see Item 1A - Risk Factors.
Natural Gas Distribution
GeneralThe Company's natural gas distribution segment is operated through its wholly
owned subsidiaries, consisting of operations from Montana-Dakota, Cascade and Intermountain. These companies sell natural gas at retail, serving residential, commercial and industrial customers in 340 communities and adjacent rural areas across eight states. They also provide natural gas transportation services to certain customers on the Company's systems. For more information on the retail customer classes served, see the table below. These services are provided through distribution systems aggregating approximately 20,600 miles. The natural gas distribution operations have obtained and hold, or are in the process of renewing, valid and existing franchises authorizing them to conduct their natural gas operations in all of the municipalities they serve where such franchises are required. These operations
intend to protect their service areas and seek renewal of all expiring franchises. At December 31, 2020, the natural gas distribution operations' net natural gas distribution plant investment was $2.0 billion and its rate base was $1.3 billion.
The retail customers served and respective revenues by class for the natural gas distribution operations were as follows:
2020
2019
2018
Customers Served
Revenues
Customers Served
Revenues
Customers Served
Revenues
(Dollars
in thousands)
Residential
887,429
$
480,466
868,821
$
479,673
850,595
$
464,697
Commercial
108,788
281,175
107,741
293,201
106,297
279,566
Industrial
929
26,217
906
26,570
835
24,555
997,146
$
787,858
977,468
$
799,444
957,727
$
768,818
Transportation
and other revenues for the natural gas distribution operations were $60.3 million, $65.8 million and $54.4 million for the years ended December 31, 2020, 2019 and 2018, respectively.
MDU Resources Group, Inc. Form 10-K 13
Part I
The
percentage of the natural gas distribution operations' retail sales revenues by jurisdiction was as follows:
2020
2019
2018
Idaho
30
%
29
%
30
%
Washington
30
%
28
%
26
%
North
Dakota
13
%
15
%
15
%
Montana
8
%
9
%
9
%
Oregon
8
%
8
%
8
%
South
Dakota
6
%
6
%
7
%
Minnesota
3
%
3
%
3
%
Wyoming
2
%
2
%
2
%
The
natural gas distribution operations are subject to regulation by the IPUC, MNPUC, MTPSC, NDPSC, OPUC, SDPUC, WUTC and WYPSC regarding retail rates, service, accounting and certain security issuances.
System Supply, System Demand and Competition The natural gas distribution operations serve retail natural gas markets, consisting principally of residential and firm commercial space and water heating users, in portions of Idaho, Minnesota, Montana, North Dakota, Oregon, South Dakota, Washington and Wyoming. These markets are highly seasonal and sales volumes depend largely on the weather, the effects of which are mitigated in certain jurisdictions by weather normalization mechanisms discussed later in Regulatory Matters. Additionally, the average customer consumption has tended to decline as more efficient appliances and furnaces are installed and as the
Company has implemented conservation programs. In addition to the residential and commercial sales, the utilities transport natural gas for larger commercial and industrial customers who purchase their own supply of natural gas.
Competition resulting from customer demands, technological advances and other factors exists between natural gas and other fuels and forms of energy. The natural gas distribution operations have established various natural gas transportation service rates for their distribution businesses to retain interruptible commercial and industrial loads. These rates have enhanced the natural gas distribution operations' competitive posture with alternative fuels, although certain customers have bypassed the distribution systems by directly accessing transmission pipelines within close proximity. These bypasses do not have a material effect on results of operations.
The
natural gas distribution operations and various distribution transportation customers obtain natural gas for their system requirements directly from producers, processors and marketers. The Company's purchased natural gas is supplied by a portfolio of contracts specifying market-based pricing and is transported under transportation agreements with WBI Energy Transmission, Northern Border Pipeline Company, Northwest Pipeline LLC, South Dakota Intrastate Pipeline, Northern Natural Gas, Gas Transmission Northwest LLC, Northwestern Energy, Viking Gas Transmission Company, Enbridge Westcoast Pipeline, Inc., Ruby Pipeline LLC, Foothills Pipe Lines Ltd., NOVA Gas Transmission Ltd, TC Energy Corporation and Northwest Natural. The natural gas distribution operations have contracts
for storage services to provide gas supply during the winter heating season and to meet peak day demand with various storage providers, including WBI Energy Transmission, Dominion Energy Questar Pipeline, LLC, Northwest Pipeline LLC, Northwest Natural and Northern Natural Gas. In addition, certain of the operations have entered into natural gas supply management agreements with various parties. Demand for natural gas, which is a widely traded commodity, has historically been sensitive to seasonal heating and industrial load requirements, as well as changes in market price. The Company believes supplies are adequate for the natural gas distribution operations to meet its system natural gas requirements for the next decade. This belief is based on current and projected domestic and regional supplies of natural gas and the pipeline transmission network currently available through its suppliers
and pipeline service providers.
Regulatory MattersThe natural gas distribution operations' retail natural gas rate schedules contain clauses permitting adjustments in rates based upon changes in natural gas commodity, transportation and storage costs. Current tariffs allow for recovery or refunds of under- or over-recovered gas costs through rate adjustments which are filed annually.
In North Dakota and South Dakota, Montana-Dakota's natural gas tariffs contain weather normalization mechanisms applicable to certain firm customers that adjust the distribution delivery charges to reflect weather fluctuations during the November 1 through May 1 billing periods.
In Montana, Montana-Dakota recovers in rates, through a tracking mechanism, its allocated share of Montana property-related taxes assessed
to natural gas operations on an after-tax basis.
In Minnesota and Washington, Great Plains and Cascade recover qualifying capital investments related to the safety and integrity of the pipeline systems through cost recovery tracking mechanisms.
In Oregon, Cascade has a decoupling mechanism in place approved by the OPUC until January 1, 2025, with a review to be completed by September 30, 2024. Cascade also has an earnings sharing mechanism with respect to its Oregon jurisdictional operations as required by the OPUC.
On July 7, 2016, the WUTC approved a full decoupling mechanism where Cascade is allowed recovery of an average revenue per customer regardless of actual consumption. The mechanism
also includes an earnings sharing component if Cascade earns beyond its authorized return. The decoupling mechanism is being reviewed by an outside consultant which will provide a report to the WUTC in March 2021.
14 MDU Resources Group, Inc. Form 10-K
Part I
On December 22, 2016, the MNPUC approved a request
by Great Plains to implement a full revenue decoupling mechanism pilot project for three years. The decoupling mechanism reflects the period January 1 through December 31. The MNPUC has adopted the administrative law judge's recommendation to extend the initial pilot period through the end of 2021. A final determination will be made as part of its pending rate case.
On May 4, 2020, Intermountain filed an application for authority to facilitate access for RNG producers to the Company's distribution system for the purpose of moving RNG to the producer's end-use customers. The request was approved by the IPUC with an effective date of June 12, 2020. The facilitation plan treats all RNG access as non-utility business and fully insulates utility customers
from any impact. It allows Intermountain to charge RNG producers for the cost of all infrastructure needed to serve the producer. It also provides a method to charge RNG producers for maintenance costs associated with the RNG projects as well as an access fee that provides a return on Intermountain's involvement. The facilitation plan will be vital in supporting the growth and development of the RNG industry in the state of Idaho.
On August 3, 2020, Intermountain filed an application for authority to implement a commercial energy efficiency program and funding mechanism. The request was approved by the IPUC with an effective date of October 1, 2020. The purpose of the program is to encourage upgrades to, or use of, high efficiency natural gas equipment. This will be achieved through the use of rebates, offered towards the purchase
and installation of qualified energy-efficient natural gas equipment.
For more information on regulatory matters, see Item 8 - Note 20.
Environmental MattersThe natural gas distribution operations are subject to federal, state and local environmental, facility-siting, zoning and planning laws and regulations. The Company believes its natural gas distribution operations are in substantial compliance with those regulations.
The Company's natural gas distribution operations are very small-quantity generators of hazardous waste, and subject only to minimum regulation under the RCRA. Washington state rule defines Cascade as a small-quantity
generator, but regulation under the rule is similar to RCRA. Certain locations of the natural gas distribution operations routinely handle PCBs from their natural gas operations in accordance with federal requirements. PCB storage areas are registered with the EPA as required. Capital and operational expenditures for natural gas distribution operations could be affected in a variety of ways by potential new GHG legislation or regulation. In particular, such legislation or regulation would likely increase capital expenditures for energy efficiency and conservation programs and operational costs associated with GHG emissions compliance. Natural gas distribution operations expect to recover the operational and capital expenditures for GHG regulatory compliance in rates consistent with the recovery of other reasonable costs of complying with environmental laws and regulations.
The natural gas distribution operations did not incur
any material environmental expenditures in 2020. Except as to what may be ultimately determined with regard to the issues described in the following paragraph, the natural gas distribution operations do not expect to incur any material capital expenditures related to environmental compliance with current laws and regulations through 2023.
Montana-Dakota has ties to six historic manufactured gas plants as a successor corporation or through direct ownership of the plant. Montana-Dakota is investigating possible soil and groundwater impacts due to the operation of two of these former manufactured gas plant sites. To the extent not covered by insurance, Montana-Dakota may seek recovery in its natural gas rates charged to customers for certain investigation and remediation costs incurred for these sites. Cascade has ties to nine historic manufactured gas plants as a successor corporation or through direct ownership of the plant.
Cascade is involved in the investigation and remediation of one of these manufactured gas plants in Washington. To the extent not covered by insurance, Cascade will seek recovery of investigation and remediation costs through its natural gas rates charged to customers.
See Item 8 - Note 21 for further discussion of certain manufactured gas plant sites.
Pipeline
GeneralWBI Energy owns and operates both regulated and non-regulated businesses. The regulated business of this segment, WBI Energy Transmission, owns and operates approximately 3,700 miles of natural gas transmission and storage lines in Minnesota, Montana, North Dakota, South Dakota and Wyoming. WBI Energy Transmission's underground
storage fields provide storage services to local distribution companies, industrial customers, natural gas marketers and others, and serve to enhance system reliability. Its system is strategically located near four natural gas producing basins, making natural gas supplies available to its transportation and storage customers. The system has 13 interconnecting points with other pipeline facilities allowing for the receipt and/or delivery of natural gas to and from other regions of the country and from Canada. Under the Natural Gas Act, as amended, WBI Energy Transmission is subject to the jurisdiction of the FERC regarding certificate, rate, service and accounting matters, and at December 31, 2020, its net plant investment was $548.3 million.
The non-regulated business of this segment provides a variety of energy-related services, including cathodic protection and energy efficiency
product sales and installation services to large end-users.
In 2020, the Company divested its regulated and non-regulated natural gas gathering assets. With the completion of these sales, the Company has exited the natural gas gathering business.
A majority of the pipeline business is transacted in the Rocky Mountain and northern Great Plains regions of the United States.
MDU Resources Group, Inc. Form 10-K 15
Part
I
System Supply, System Demand and CompetitionNatural gas supplies emanate from traditional and nontraditional production activities in the region from both on-system and off-system supply sources. Incremental supply from nontraditional sources, such as the Bakken area in Montana and North Dakota, have helped offset declines in traditional regional supply sources and supports WBI Energy Transmission's transportation and storage services. In addition, off-system supply sources are available through the Company's interconnections with other pipeline systems. WBI Energy Transmission continues to look for opportunities to increase transportation
and storage services through system expansion and/or other pipeline interconnections or enhancements that could provide future benefits.
WBI Energy Transmission's underground natural gas storage facilities have a certificated storage capacity of approximately 350 Bcf, including 193 Bcf of working gas capacity, 83 Bcf of cushion gas and 74 Bcf of native gas. These storage facilities enable customers to purchase natural gas throughout the year and meet winter peak requirements.
WBI Energy Transmission competes with several pipelines for its customers' transportation and storage business and at times may discount rates in an effort to retain market share; however, the strategic location of its system near four natural gas producing basins and the availability of underground storage services, along with interconnections with other pipelines, enhances its competitive position.
Although
certain of WBI Energy Transmission's firm customers, including its largest firm customer Montana-Dakota, serve relatively secure residential, commercial and industrial end-users, they generally all have some price-sensitive end-users that could switch to alternate fuels.
WBI Energy Transmission transports substantially all of Montana-Dakota's natural gas, primarily utilizing firm transportation agreements, which for 2020 represented 23 percent of WBI Energy Transmission's subscribed firm transportation contract demand. The majority of the firm transportation agreements with Montana-Dakota expire in June 2022. In addition, Montana-Dakota has contracts, expiring in July 2035, with WBI Energy Transmission to provide firm storage services to facilitate
meeting Montana-Dakota's winter peak requirements.
The non-regulated business of this segment competes for existing customers in the areas in which it operates. Its focus on customer service and the variety of services it offers serve to enhance its competitive position.
Environmental MattersThe pipeline operations are subject to federal, state and local environmental, facility-siting, zoning and planning laws and regulations.
Administration of certain provisions of federal environmental laws is delegated to the states where WBI Energy and its subsidiaries operate. Administering agencies may issue permits with varying terms and operational compliance conditions. Permits are renewed and modified, as necessary,
based on defined permit expiration dates, operational demand, facility upgrades or modifications, and/or regulatory changes. The Company believes it is in substantial compliance with these regulations.
Detailed environmental assessments and/or environmental impact statements as required by the National Environmental Policy Act are included in the FERC's environmental review process for both the construction and abandonment of WBI Energy Transmission's natural gas transmission pipelines, compressor stations and storage facilities.
The pipeline operations did not incur any material environmental expenditures in 2020 and do not expect to incur any material capital expenditures related to environmental compliance with current laws and regulations through 2023.
Construction
Materials and Contracting
GeneralKnife River operates construction materials and contracting businesses headquartered in Alaska, California, Hawaii, Idaho, Iowa, Minnesota, Montana, North Dakota, Oregon, South Dakota, Texas, Washington and Wyoming. Knife River mines, processes and sells construction aggregates (crushed stone, sand and gravel); produces and sells asphalt mix; and supplies ready-mixed concrete. These products are used in most types of construction, performed by Knife River and other companies, including roads, freeways and bridges, as well as homes, schools, shopping centers, office buildings and industrial parks. Knife River focuses on vertical integration of its contracting services with its construction materials to support the aggregate-based product lines including aggregate placement, asphalt and concrete paving, and site development and grading. Although not common
to all locations, other products include the sale of cement, liquid asphalt for various commercial and roadway applications, various finished concrete products and other building materials and related contracting services.
During 2020, Knife River acquired the assets of Oldcastle Infrastructure Spokane, a prestressed-concrete business in Spokane, Washington, and McMurry Ready-Mix Co., an aggregates and concrete supplier in Casper, Wyoming. For more information on business combinations, see Item 8 - Note 4.
CompetitionKnife River's construction materials products and contracting services are marketed under competitive conditions. Price is the principal competitive force to which these products and services are subject, with service, quality, delivery time and proximity to the customer also being significant factors. Knife River focuses
on markets located near aggregate sites to reduce transportation costs which allows Knife River to remain competitive with the pricing of aggregate products. The number and size of competitors varies in each of Knife River's principal market areas and product lines.
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Part I
The demand for construction materials products
and contracting services is significantly influenced by the cyclical nature of the construction industry. In addition, activity in certain locations may be seasonal in nature due to the effects of weather. The key economic factors affecting product demand are changes in the level of local, state and federal governmental spending on roads and infrastructure projects, general economic conditions within the market area that influence the commercial and residential sectors, and prevailing interest rates.
Knife River's customers are a diverse group which includes federal, state and municipal government agencies, commercial and residential developers, and private parties. The mix of sales by customer class varies each year depending on available work. Knife River is not dependent on any single customer or group of customers for sales of its products and services, the loss of which would have a material adverse effect on its construction
materials businesses.
Reserve Information Aggregate reserve estimates are calculated based on the best available data. This data is collected from drill holes and other subsurface investigations, as well as investigations of surface features such as mine high walls and other exposures of the aggregate reserves. Mine plans, production history and geologic data are also utilized to estimate reserve quantities.
Estimates are based on analyses of the data described above by experienced internal mining engineers, operating personnel and geologists. Property setbacks and other regulatory restrictions and limitations are identified to determine the total area available for mining. Data described previously are used to calculate the thickness of aggregate materials to be recovered.
Topography associated with alluvial sand
and gravel deposits is typically flat and volumes of these materials are calculated by applying the thickness of the resource over the areas available for mining. Volumes are then converted to tons by using an appropriate conversion factor. Typically, 1.5 tons per cubic yard in the ground is used for sand and gravel deposits.
Topography associated with hard rock reserves is typically much more diverse. Therefore, using available data, a final topography map is created and computer software is utilized to compute the volumes between the existing and final topographies. Volumes are then converted to tons by using an appropriate conversion factor. Typically, 2 tons per cubic yard in the ground is used for hard rock quarries.
Estimated reserves are probable reserves as defined in Securities Act Industry Guide 7. The reserve estimates include only salable tonnage and thus exclude waste materials
that are generated in the crushing and processing phases of the operation. Approximately 1.0 billion tons of Knife River's 1.1 billion tons of aggregate reserves are permitted reserves. Remaining reserves are based on estimates of volumes that can be economically extracted and sold to meet current market and product applications. The remaining reserves are on properties that are expected to be permitted for mining under current regulatory requirements. The data used to calculate the remaining reserves may require revisions in the future to account for changes in customer requirements and unknown geological occurrences. The remaining reserve life (years) was calculated by dividing remaining reserves by the three-year average sales, including estimated sales from acquired reserves prior to acquisition, from 2018 through 2020. Actual useful lives of these reserves will be subject to, among other things, fluctuations in customer demand, customer specifications, geological
conditions and changes in mining plans.
* Includes
estimate of three-year average sales for acquired reserves.
The 1.1 billion tons of estimated aggregate reserves at December 31, 2020, are comprised of 581 million tons on properties that are owned and 524 million tons that are leased. Approximately 40 percent of the tons under lease have lease expiration dates of 20 years or more. The weighted average years remaining on all leases containing estimated probable aggregate reserves is approximately 20 years, including options for renewal that are at Knife River's discretion. Based on a three-year average of sales from 2018 through 2020 of leased reserves, the average time necessary to produce remaining aggregate reserves from such leases is approximately 45 years.
Some sites have leases that expire prior to the exhaustion of the estimated reserves. The estimated reserve life assumes, based on Knife River's experience, that leases will be renewed to allow sufficient time to fully recover these reserves.
The changes in Knife River's aggregate reserves for the years ended December 31 were as follows:
2020
2019
2018
(000's
of tons)
Aggregate reserves:
Beginning of year
1,054,186
1,014,431
965,036
Acquisitions (a)
114,666
71,157
81,004
Sales
volumes (b)
(28,477)
(28,121)
(25,046)
Other (c)
(35,488)
(3,281)
(6,563)
End of year
1,104,887
1,054,186
1,014,431
(a) Includes
reserves from recent business combinations.
(b) Excludes sales from other sources.
(c) Includes property sales, revisions of previous estimates and expiring leases.
Environmental MattersKnife River's construction materials and contracting operations are subject to regulation customary for such operations, including federal, state and local environmental compliance and reclamation regulations. Except as to the issues described later, Knife River believes it is in substantial compliance with these regulations. Individual permits applicable to Knife River's various operations are managed and tracked as they relate to the statuses
of the application, modification, renewal, compliance and reporting procedures.
Knife River's asphalt and ready-mixed concrete manufacturing plants and aggregate processing plants are subject to the Clean Air Act and the Clean Water Act requirements for controlling air emissions and water discharges. Some mining and construction activities are also subject to these laws. In most of the states where Knife River operates, these regulatory programs are delegated to state and local regulatory authorities. Knife River's facilities are also subject to the RCRA as it applies to the management of hazardous wastes and underground storage tank systems. These programs are generally delegated to the state and local authorities in the states where Knife River operates. Knife River's facilities must comply with requirements for managing wastes and underground storage tank systems.
18 MDU
Resources Group, Inc. Form 10-K
Part I
Certain activities of Knife River are directly regulated by federal agencies. For example, certain in-water mining operations are subject to provisions of the Clean Water Act that are administered by the Army Corps. Knife River has several such operations, including gravel bar skimming and dredging operations, and Knife River has the associated required permits. The expiration dates of these permits vary, with five years generally being the longest term.
Knife River's operations are also occasionally
subject to the ESA. For example, land use regulations often require environmental studies, including wildlife studies, before a permit may be granted for a new or expanded mining facility or an asphalt or concrete plant. If endangered species or their habitats are identified, ESA requirements for protection, mitigation or avoidance apply. Endangered species protection requirements are usually included as part of land use permit conditions. Typical conditions include avoidance, setbacks, restrictions on operations during certain times of the breeding or rearing season, and construction or purchase of mitigation habitat. Knife River's operations are also subject to state and federal cultural resources protection laws when new areas are disturbed for mining operations or processing plants. Land use permit applications generally require that areas proposed for mining or other surface disturbances be surveyed for cultural resources. If any are identified, they must be protected
or managed in accordance with regulatory agency requirements.
The most comprehensive environmental permit requirements are usually associated with new mining operations, although requirements vary widely from state to state and even within states. In some areas, land use regulations and associated permitting requirements are minimal. However, some states and local jurisdictions have very demanding requirements for permitting new mines. Environmental impact reports are sometimes required before a mining permit application can be considered for approval. These reports can take up to several years to complete. The report can include projected impacts of the proposed project on air and water quality, wildlife, noise levels, traffic, scenic vistas and other environmental factors. The reports generally include suggested actions to mitigate the projected adverse impacts.
Provisions for public
hearings and public comments are usually included in land use permit application review procedures in the counties where Knife River operates. After considering environmental, mine plan and reclamation information provided by the permittee, as well as comments from the public and other regulatory agencies, the local authority approves or denies the permit application. Denial is rare, but land use permits often include conditions that must be addressed by the permittee. Conditions may include property line setbacks, reclamation requirements, environmental monitoring and reporting, operating hour restrictions, financial guarantees for reclamation, and other requirements intended to protect the environment or address concerns submitted by the public or other regulatory agencies.
Knife River has been successful in obtaining mining and other land use permits so sufficient permitted reserves are available to support its operations.
For mining operations, this often requires considerable advanced planning to ensure sufficient time is available to complete the permitting process before the newly permitted aggregate reserve is needed to support Knife River's operations.
Knife River's Gascoyne surface coal mine last produced coal in 1995 but continues to be subject to reclamation requirements of the Surface Mining Control and Reclamation Act, as well as the North Dakota Surface Mining Act. Portions of the Gascoyne Mine remain under reclamation bond until the 10-year revegetation liability period has expired. A portion of the original permit has been released from bond and additional areas are currently in the process of having the bond released. Knife River intends to request bond release as soon as it is deemed possible.
Knife River did not incur any material environmental expenditures in 2020 and, except as to what
may be ultimately determined with regard to the issues described in the following paragraph, Knife River does not expect to incur any material capital expenditures related to environmental compliance with current laws and regulations through 2023.
In December 2000, Knife River - Northwest was named by the EPA as a PRP in connection with the cleanup of a commercial property site, acquired by Knife River - Northwest in 1999, and part of the Portland, Oregon, Harbor Superfund Site. For more information, see Item 8 - Note 21.
Mine SafetyThe Dodd-Frank Act requires disclosure of certain mine safety information. For more information, see Item 4 - Mine Safety Disclosures.
Construction
Services
General MDU Construction Services provides inside and outside specialty contracting services in 44 states plus Washington D.C. Its inside services include design, construction and maintenance of electrical and communication wiring and infrastructure, fire suppression systems, and mechanical piping and services. Its outside services include design, construction and maintenance of overhead and underground electrical distribution and transmission lines, substations, external lighting, traffic signalization, and gas pipelines, as well as utility excavation and the manufacture and distribution of transmission line construction equipment. This segment also constructs and maintains renewable energy projects. These specialty contracting services are provided to utilities and large manufacturing, commercial, industrial, institutional and governmental customers.
During
2020, MDU Construction Services acquired PerLectric, Inc., an electrical construction company in Fairfax, Virginia. For more information on business combinations, see Item 8 - Note 4.
Construction and maintenance crews are active year round. However, activity in certain locations may be seasonal in nature due to the effects of weather. MDU Construction Services works with the National Electrical Contractors Association, the IBEW and other trade associations on hiring and recruiting a qualified workforce.
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I
MDU Construction Services operates a fleet of owned and leased trucks and trailers, support vehicles and specialty construction equipment, such as backhoes, excavators, trenchers, generators, boring machines and cranes. In addition, as of December 31, 2020, MDU Construction Services owned or leased facilities in 17 states. This space is used for offices, equipment yards, manufacturing, warehousing, storage and vehicle shops.
CompetitionMDU Construction Services operates in a highly competitive business environment. Most of MDU Construction Services' work is obtained on the basis of competitive bids or by negotiation of either
cost-plus or fixed-price contracts. Its workforce and equipment are highly mobile, providing greater flexibility in the size and location of MDU Construction Services' market area. Competition is based primarily on price and reputation for quality, safety and reliability. The size and location of the services provided, as well as the state of the economy, are factors in the number of competitors that MDU Construction Services will encounter on any particular project. MDU Construction Services believes the diversification of the services it provides, the markets it serves in the United States and the quality and management of its workforce enable it to effectively operate in this competitive environment.
Utilities and independent contractors represent the largest customer base for this segment. Accordingly, utility and subcontract work accounts
for a significant portion of the work performed by MDU Construction Services and the amount of construction contracts is dependent on the level and timing of maintenance and construction programs undertaken by customers. MDU Construction Services relies on repeat customers and strives to maintain successful long-term relationships with its customers. The mix of sales by customer class varies each year depending on available work. MDU Construction Services is not dependent on any single customer or group of customers for sales of its products and services, the loss of which would have a material adverse effect on its business.
Environmental Matters MDU Construction Services' operations are subject to regulation customary for the industry, including federal, state and local environmental compliance. MDU Construction
Services believes it is in substantial compliance with these regulations.
The nature of MDU Construction Services' operations is such that few, if any, environmental permits are required. Operational convenience supports the use of petroleum storage tanks in several locations, which are permitted under state programs authorized by the EPA. MDU Construction Services has no ongoing remediation related to releases from petroleum storage tanks. MDU Construction Services' operations are conditionally exempt small-quantity waste generators, subject to minimal regulation under the RCRA. Federal permits for specific construction and maintenance jobs that may require these permits are typically obtained by the hiring entity, and not by MDU Construction Services.
MDU Construction Services did not incur any material environmental expenditures in 2020 and does not expect to incur any material capital
expenditures related to environmental compliance with current laws and regulations through 2023.
Item 1A. Risk Factors
The Company's business and financial results are subject to a number of risks and uncertainties, including those set forth below and in other documents filed with the SEC. The factors and other matters discussed herein are important factors that could cause actual results or outcomes for the Company to differ materially from those discussed in the forward-looking statements included elsewhere in this document. If any of the risks described below actually occur, the
Company's business, prospects, financial condition or financial results could be materially harmed. The following are the most material risk factors applicable to the Company and are not necessarily listed in order of importance or probability of occurrence.
Economic Risks
The Company is subject to government regulations that may have a negative impact on its business and its results of operations and cash flows. Statutory and regulatory requirements also may limit another party's ability to acquire the Company or impose conditions on an acquisition of or by the Company.
The
Company's electric and natural gas transmission and distribution businesses are subject to comprehensive regulation by federal, state and local regulatory agencies with respect to, among other things, allowed rates of return and recovery of investments and costs, financing, rate structures, customer service, health care coverage and costs, taxes, franchises; recovery of purchased power and purchased natural gas costs; and construction and siting of generation and transmission facilities. These governmental regulations significantly influence the Company's operating environment and may affect its ability to recover costs from its customers. The Company is unable to predict the impact on operating results from future regulatory activities of any of these agencies. Changes in regulations or the imposition
of additional regulations could have an adverse impact on the Company's results of operations and cash flows.
There can be no assurance that applicable regulatory commissions will determine that the Company's electric and natural gas transmission and distribution businesses' costs have been prudent, which could result in the disallowance of costs in setting rates for customers. Also, the regulatory process of approving rates for these businesses may not allow for timely and full recovery of the costs of providing services or a return on the Company's invested capital. Changes in regulatory requirements or operating conditions may require early retirement of certain assets. While
regulation typically provides rate recovery for these retirements, there is no assurance regulators will allow full recovery of all remaining costs, which could leave stranded asset costs. Rising fuel costs could increase the risk that the utility businesses will not be able to fully recover those fuel costs from customers.
Approval from federal and state regulatory agencies would be needed for acquisition of the Company, as well as for certain acquisitions by the Company. The approval process could be lengthy and the outcome uncertain, which may deter potential acquirers from approaching the Company or impact the
Company's ability to pursue acquisitions.
20 MDU Resources Group, Inc. Form 10-K
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Economic volatility affects the Company's operations, as well as the demand for its products and services.
Unfavorable economic conditions can negatively
affect the level of public and private expenditures on projects and the timing of these projects which, in turn, can negatively affect demand for the Company's products and services, primarily at the Company's construction businesses. The level of demand for construction products and services could be adversely impacted by the economic conditions in the industries the Company serves, as well as in the general economy. State and federal budget issues affect the funding available for infrastructure spending.
Economic conditions and population growth affect the electric and natural gas distribution businesses' growth in service territory, customer base and usage demand. Economic volatility
in the markets served, along with economic conditions such as increased unemployment which could impact the ability of the Company's customers to make payments, could adversely affect the Company's results of operations, cash flows and asset values. Further, any material decreases in customers' energy demand, for economic or other reasons, could have an adverse impact on the Company's earnings and results of operations.
The Company's operations involve risks that may result from catastrophic events.
The
Company's operations, particularly those related to natural gas and electric transmission and distribution, include a variety of inherent hazards and operating risks, such as product leaks; explosions; mechanical failures; vandalism; fires; pandemics; social or civil unrest; protests and riots; natural disasters; acts of terrorism; and acts of war. These hazards and operating risks could result in loss of human life; personal injury; property damage; environmental pollution; impairment of operations; and substantial financial losses. The Company maintains insurance against some, but not all, of these risks and losses. A significant incident could also increase regulatory scrutiny and result in penalties and higher amounts of capital expenditures and operational costs. Losses not fully covered by insurance could have an adverse effect on the
Company’s financial position, results of operations and cash flows.
A disruption of the regional electric transmission grid or interstate natural gas infrastructure could negatively impact the Company's business and reputation. Because the Company's electric and natural gas utility and pipeline systems are part of larger interconnecting systems, a disruption could result in a significant decrease in revenues and system repair costs negatively impacting the Company's financial position, results of operations and cash flows.
The Company is subject to capital
market and interest rate risks.
The Company's operations, particularly its electric and natural gas transmission and distribution businesses, require significant capital investment. Consequently, the Company relies on financing sources and capital markets as sources of liquidity for capital requirements not satisfied by cash flows from operations. If the Company is not able to access capital at competitive rates, including through its "at-the-market" offering program, the ability to implement business plans, make capital expenditures or pursue acquisitions the Company would otherwise rely on for future
growth may be adversely affected. Market disruptions may increase the cost of borrowing or adversely affect the Company's ability to access one or more financial markets. Such disruptions could include:
•A significant economic downturn.
•The financial distress of unrelated industry leaders in the same line of business.
•Deterioration in capital market conditions.
•Turmoil in the financial services industry.
•Volatility in commodity prices.
•Pandemics, including COVID-19.
•Terrorist
attacks.
•Cyberattacks.
The issuance of a substantial amount of the Company's common stock, whether issued in connection with an acquisition or otherwise, or the perception that such an issuance could occur, could have a dilutive effect on shareholders and/or may adversely affect the market price of the Company's common stock. Higher interest rates on borrowings could also have an adverse effect on the Company's operating results.
Financial market changes could impact the Company’s pension
and postretirement benefit plans and obligations.
The Company has pension and postretirement defined benefit plans for some of its employees and former employees. Assumptions regarding future costs, returns on investments, interest rates and other actuarial assumptions have a significant impact on the funding requirements and expense recorded relating to these plans. Adverse changes in economic indicators, such as consumer spending, inflation data, interest rate changes, political developments and threats of terrorism, among other things, can create volatility in the financial markets. These changes could impact the assumptions and negatively affect the value of assets held in the Company's pension and other postretirement benefit plans and may increase the amount and accelerate
the timing of required funding contributions for those plans.
Significant changes in energy prices could negatively affect the Company's businesses.
Fluctuations in oil and natural gas production, supplies and prices; fluctuations in commodity price basis differentials; political and economic conditions in oil-producing countries; actions of the Organization of Petroleum Exporting Countries; demand for oil due to the economic slowdowns; and other external factors impact the development of oil and natural gas supplies and the expansion and operation of natural gas pipeline systems. The Company has benefited from associated natural gas production in the Bakken, which has provided opportunities for organic growth projects.
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Resources Group, Inc. Form 10-K 21
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Depressed oil and natural gas prices, however, place pressure on the ability of oil exploration and production companies to meet credit requirements and will continue to be a challenge if prices remain depressed long-term. Prolonged depressed prices for oil and natural gas could negatively affect the growth, results of operations, cash flows and asset values of the Company's electric, natural gas and pipeline businesses.
If
oil and natural gas prices increase significantly, customer demand could decline for utility, pipeline and construction materials, which could impact the Company's results of operations and cash flows. While the Company has fuel clause recovery mechanisms for its utility operations in all of the states where it operates, higher utility fuel costs could also significantly impact results of operations if such costs are not recovered. Delays in the collection of utility fuel cost recoveries, as compared to expenditures for fuel purchases, could also negatively impact the Company's cash flows. High oil prices also affect the cost and demand for asphalt products and related contracting services.
COVID-19
may have a negative impact on the Company's business operations, revenues, results of operations, liquidity and cash flows.
To the extent the COVID-19 pandemic adversely affects the Company's business, operations, revenues, liquidity or cash flows, it may also have the effect of heightening many of the other risks described in this section. The degree to which COVID-19 will impact the Company depends on future developments, including severity and duration of the outbreak, actions taken by governmental authorities, timing and effectiveness of vaccines being administered, and timing of when relatively normal economic and operating conditions resume.
The
Company's operations have experienced some disruptions due to its employees or third-party employees being diagnosed with COVID-19 or other illnesses and required quarantine periods for those in close contact to COVID-19. Self-quarantine or actual viral health issues may have a negative impact on the Company's employees and the ability to continue its work activities under a normal course of business. Moreover, the diagnosis of COVID-19 or other illnesses could require the Company or its business partners to suspend projects, quarantine employees or institute more aggressive preventive measures including closure of job sites. Mandated healthcare protocols could lead to a shortage of employees or altered operations. If a significant percentage of the
Company's workforce are unable to work because of illness, quarantine or government restrictions in connection with the COVID-19 pandemic, the Company's operations may be negatively impacted, potentially adversely affecting its business, operations, revenues, liquidity and cash flows.
A portion of the Company's workforce has been working remotely and the Company has delayed return to work processes for certain office employees due to the rise in local COVID-19 cases in some operating regions. To date, the Company has not experienced any significant delays or information technology disruptions.
An increased amount of social engineering and attacks by bad actors taking advantage of the pandemic could affect the Company's ability to maintain secure operations, communications and productivity in the future.
The regulated businesses have been deemed essential service providers and have seen some impacts on their businesses; however, the Company could be materially affected if its businesses were no longer deemed essential service providers. Future actions of its regulatory commissions on accounting for the impacts of the COVID-19 pandemic may also affect the Company's future operating results and cash flows. The
Company has experienced some impacts to its commercial and industrial electric and natural gas loads associated with reduced demand from those customers due to the COVID-19 pandemic.
The construction businesses have generally been deemed essential service providers and have experienced some inefficiencies and interruptions on its businesses from the pandemic; however, the Company could be materially impacted if its businesses were no longer deemed essential service providers. These businesses could be further impacted in the future by site closures, government shut-down measures, additional inefficiencies due to compliance with safety and social distancing measures, public and private sector budget changes and constraints, and the impact of overall macro and local economic conditions on future construction projects.
Other
factors associated with the COVID-19 pandemic that could impact the Company's businesses and future operating results, revenues and liquidity include impacts related to the health, safety, and availability of its employees and contractors; continued flexible payment plans; counterparty credit; costs and availability of supplies; capital construction and infrastructure operation and maintenance programs; financing plans; pension valuations; travel restrictions; and legal and regulatory matters, including the potential for delayed regulatory filings and recovery of invested capital.
Reductions in the Company's credit ratings could increase financing costs.
There is no assurance the
Company's current credit ratings, or those of its subsidiaries, will remain in effect or that a rating will not be lowered or withdrawn by a rating agency. Events affecting the Company's financial results may impact its cash flows and credit metrics, potentially resulting in a change in the Company's credit ratings. The Company's credit ratings may also change as a result of the differing methodologies or changes in the methodologies used by the rating agencies.
Increasing costs associated with health care plans may adversely affect the
Company's results of operations.
The Company's self-insured costs of health care benefits for eligible employees continues to increase. Increasing quantities of large individual health care claims and an overall increase in total health care claims could have an adverse impact on operating results, financial position and liquidity. Legislation related to health care could also change the Company's benefit program and costs.
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The Company is exposed to risk of loss resulting from the nonpayment and/or nonperformance by the Company's customers and counterparties.
If the Company's customers or counterparties experience financial difficulties, the Company could experience difficulty in collecting receivables. Nonpayment and/or nonperformance by the
Company's customers and counterparties, particularly customers and counterparties of the Company’s construction materials and contracting and construction services businesses for large construction projects, could have a negative impact on the Company's results of operations and cash flows. The Company could also have indirect credit risk from participating in energy markets such as MISO in which credit losses are socialized to all participants.
Changes in tax law may negatively affect the Company's business.
Changes to federal, state and local tax laws
have the ability to benefit or adversely affect the Company's earnings and customer costs. Significant changes to corporate tax rates could result in the impairment of deferred tax assets that are established based on existing law at the time of deferral. Changes to the value of various tax credits could change the economics of resources and the resource selection for the electric generation business. Regulation incorporates changes in tax law into the rate-setting process for the regulated energy delivery businesses which could create timing delays before the impact of changes are realized.
The Company's operations could be negatively impacted by import tariffs and/or other government mandates.
The
Company operates in or provides services to capital intensive industries in which federal trade policies could significantly impact the availability and cost of materials. Imposed and proposed tariffs could significantly increase the prices and delivery lead times on raw materials and finished products that are critical to the Company and its customers, such as aluminum and steel. Prolonged lead times on the delivery of raw materials and further tariff increases on raw materials and finished products could adversely affect the Company's business, financial condition and results of operations.
Operational Risks
Significant portions of the Company’s natural
gas pipelines and power generation and transmission facilities are aging. The aging infrastructure may require significant additional maintenance or replacement that could adversely affect the Company’s results of operations.
The Company’s energy delivery infrastructure is aging, which increases certain risks, including breakdown or failure of equipment, pipeline leaks and fires developing from power lines. Aging infrastructure is more prone to failure which increases maintenance costs, unplanned outages and the need to replace facilities. Even if properly maintained, reliability may ultimately deteriorate and negatively affect the Company’s ability to serve its customers, which
could result in increased costs associated with regulatory oversight. The costs associated with maintaining the aging infrastructure and capital expenditures for new or replacement infrastructure could cause rate volatility and/or regulatory lag in some jurisdictions. If, at the end of its life, the investment costs of a facility have not been fully recovered, the Company may be adversely affected if commissions do not allow such costs to be recovered in rates. Such impacts of an aging infrastructure, could adversely affect the Company’s results of operations and cash flows.
Additionally, hazards from aging infrastructure could result in serious injury, loss of human life, significant damage to property, environmental impacts and impairment of operations, which
in turn could lead to substantial financial losses. The location of facilities near populated areas, including residential areas, business centers, industrial sites and other public gathering places, could increase the damages resulting from these risks. A major incident involving another natural gas system could lead to additional capital expenditures, increased regulation, and fines and penalties on natural gas utilities. The occurrence of any of these events could adversely affect the Company’s results of operations, financial position and cash flows.
The Company's utility and pipeline operations are subject to planning risks.
Most electric and natural gas utility investments, including natural gas transmission pipeline investments,
are made with the intent of being used for decades. In particular, electric transmission and generation resources are planned well in advance of when they are placed into service based upon resource plans using assumptions over the planning horizon including sales growth, commodity prices, equipment and construction costs, regulatory treatment, available technology and public policy. Public policy changes and technology advancements related to areas such as energy efficient appliances and buildings, renewable and distributive electric generation and storage, carbon dioxide emissions, electric vehicle penetration, restrictions on or disallowance of new or existing services, and natural gas availability and cost may significantly impact the planning assumptions. Changes in critical planning assumptions may result in excess generation, transmission and distribution resources creating increased per customer costs and downward pressure on load growth. These changes could
also result in a stranded investment if the Company is unable to fully recover the costs of its investments.
The regulatory approval, permitting, construction, startup and/or operation of pipelines, power generation and transmission facilities, and aggregate reserves may involve unanticipated events, delays and unrecoverable costs.
The construction, startup and operation of natural gas pipelines and electric power generation and transmission facilities involve many risks, which may include delays; breakdown or failure of equipment; inability to obtain required governmental permits and approvals; inability to obtain or renew easements; public opposition; inability to complete financing; inability to negotiate acceptable equipment acquisition, construction, fuel supply, off-take, transmission, transportation or
other material agreements; changes in markets and market prices for power; cost increases and overruns; the risk of performance below expected levels of output or efficiency; and the inability to obtain full cost recovery in regulated rates. Additionally, in a number of states in which the Company operates, it can be difficult to permit new aggregate sites or expand existing aggregate sites due to community resistance. Such unanticipated events could negatively impact the Company's business, its results of operations and cash flows.
MDU Resources Group, Inc.
Form 10-K 23
Part I
Operating or other costs required to comply with current or potential pipeline safety regulations and potential new regulations under various agencies could be significant. The regulations require verification of pipeline infrastructure records by pipeline owners and operators to confirm the maximum allowable operating pressure of certain lines. Increased emphasis on pipeline safety and increased regulatory scrutiny may result in penalties and higher costs of operations. If these costs are not fully recoverable from customers, they could have an adverse effect on the
Company’s results of operations and cash flows.
The backlogs at the Company's construction materials and contracting and construction services businesses may not accurately represent future revenue.
Backlog consists of the uncompleted portion of services to be performed under job-specific contracts. Contracts are subject to delay, default or cancellation, and contracts in the Company's backlog are subject to changes in the scope of services to be provided,
as well as adjustments to the costs relating to the applicable contracts. Backlog may also be affected by project delays or cancellations resulting from weather conditions, external market factors and economic factors beyond the Company's control. Accordingly, there is no assurance that backlog will be realized. The timing of contract awards, duration of large new contracts and the mix of services can significantly affect backlog. Backlog at any given point in time may not accurately represent the revenue or net income that is realized in any period. Also, the backlog as of the end of the year may not be indicative of the
revenue and net income expected to be earned in the following year and should not be relied upon as a stand-alone indicator of future revenues or net income.
Environmental and Regulatory Risks
The Company's operations could be adversely impacted by climate change.
Severe weather events, such as tornadoes, hurricanes, rain, ice and snowstorms and high and low temperature extremes, occur in regions in which the Company operates and maintains infrastructure. Climate change could change the frequency and severity of these weather events, which may create physical and financial risks to the Company. Such risks could have
an adverse effect on the Company's financial condition, results of operations and cash flows.
Severe weather events may damage or disrupt the Company's electric and natural gas transmission and distribution facilities, which could result in disruption of service and ability to meet customer demand, increased maintenance or capital costs to repair facilities and restore customer service. The cost of providing service could increase to the extent the frequency of severe weather events increases because of climate change or otherwise. The Company may not recover all costs related to mitigating these physical risks.
Increases in severe weather
conditions or extreme temperatures may cause infrastructure construction projects to be delayed or canceled and limit resources available for such projects resulting in decreased revenue or increased project costs at the construction materials and contracting and construction services businesses. In addition, drought conditions could restrict the availability of water supplies, inhibiting the ability of the construction businesses to conduct operations.
Utility customers’ energy needs vary with weather conditions, primarily temperature and humidity. For residential customers, heating and cooling represent the largest energy use. To the extent weather conditions are affected by climate change, customers’ energy use could increase or decrease. Increased energy use by its utility customers due to weather may require the Company to invest in additional
generating assets, transmission and other infrastructure to serve increased load. Decreased energy use due to weather may result in decreased revenues. Extreme weather conditions, such as uncommonly long periods of high or low ambient temperature, in general require more system backup, adding to costs, and can contribute to increased system stress, including service interruptions. Weather conditions outside of the Company's service territory could also have an impact on revenues. The Company buys and sells electricity that might be generated outside its service territory, depending upon system needs and market opportunities. Extreme temperatures may create high energy demand and raise electricity prices, which could increase the cost of energy provided to customers.
Climate
change may impact a region’s economic health, which could impact revenues at all of the Company's businesses. The Company's financial performance is tied to the health of the regional economies served. The Company provides natural gas and electric utility service, as well as construction materials and services, for some states and communities that are economically affected by the agriculture industry. Increases in severe weather events or significant changes in temperature and precipitation patterns could adversely affect the agriculture industry and, correspondingly, the economies of the states and communities affected by that industry.
The insurance industry may be adversely affected
by severe weather events which may impact the availability of insurance coverage, insurance premiums and insurance policy terms.
The Company may be subject to litigation related to climate change. Costs of such litigation could be significant, and an adverse outcome could require substantial capital expenditures, changes in operations and possible payment of penalties or damages, which could affect the Company's results of operations and cash flows if the costs are not recoverable in rates.
The price of energy also has an impact on the economic health of communities. The cost of additional regulatory requirements to combat climate change, such as regulation of carbon dioxide emissions under the Clean Air Act, requirements
to replace fossil-fuels with renewable energy or credits, or other environmental regulation or taxes could impact the availability of goods and the prices charged by suppliers, which would normally be borne by consumers through higher prices for energy and purchased goods, and could adversely impact economic conditions of areas served by the
24 MDU Resources Group, Inc. Form 10-K
Part I
Company.
To the extent financial markets view climate change and emissions of GHGs as a financial risk, this could negatively affect the Company's ability to access capital markets or cause less than ideal terms and conditions.
The Company's operations are subject to environmental laws and regulations that may increase costs of operations, impact or limit business plans, or expose the Company to environmental liabilities.
The Company is subject to environmental laws and regulations affecting many aspects of its operations, including air and water quality, wastewater discharge,
the generation, transmission and disposal of solid waste and hazardous substances, aggregate permitting and other environmental considerations. These laws and regulations can increase capital, operating and other costs; cause delays as a result of litigation and administrative proceedings; and create compliance, remediation, containment, monitoring and reporting obligations, particularly relating to electric generation, permitting and environmental compliance for construction material facilities, and natural gas transmission and storage operations. Environmental laws and regulations can also require the Company to install pollution control equipment at its facilities, clean up spills and other contamination and correct environmental hazards, including payment of all or part of the cost to remediate sites where the
Company's past activities, or the activities of other parties, caused environmental contamination. These laws and regulations generally require the Company to obtain and comply with a variety of environmental licenses, permits, inspections and other approvals and may cause the Company to shut down existing facilities due to difficulties in assuring compliance or where the cost of compliance makes operation of the facilities uneconomical. Although the Company strives to comply with all applicable environmental laws and regulations, public and private entities and private individuals may interpret the Company's legal or regulatory requirements
differently and seek injunctive relief or other remedies against the Company. The Company cannot predict the outcome, financial or operational, of any such litigation or administrative proceedings.
Existing environmental laws and regulations may be revised and new laws and regulations seeking to protect the environment may be adopted or become applicable to the Company. These laws and regulations could require the Company to limit the use or output of certain facilities; restrict the use of certain fuels; prohibit or restrict new or existing services; replace certain fuels with renewable fuels; retire
and replace certain facilities; install pollution controls; remediate environmental impacts; remove or reduce environmental hazards; or forego or limit the development of resources. Revised or new laws and regulations that increase compliance costs or restrict operations, particularly if costs are not fully recoverable from customers, could adversely affect the Company's results of operations and cash flows.
Initiatives related to global climate change and to reduce GHG emissions could adversely impact the Company's operation, costs of or access to capital and impact or limit business plans.
Concern that GHG emissions contribute to global climate change has led to international, federal, state and local legislative and regulatory
proposals to reduce or mitigate the effects of GHG emissions. The Company’s primary GHG emission is carbon dioxide from fossil fuels combustion at Montana-Dakota's electric generating facilities, particularly its coal-fired facilities. Approximately 46 percent of Montana-Dakota's owned generating capacity and approximately 70 percent of the electricity it generated in 2020 was from coal-fired facilities.
Treaties, legislation or regulations to reduce GHG emissions in response to climate change may be adopted that affect the Company's utility operations by requiring additional energy conservation efforts or renewable energy sources, limiting emissions, imposing carbon taxes or other compliance costs; as well as other mandates that could significantly increase capital
expenditures and operating costs or reduce demand for the Company's utility services. If the Company’s utility operations do not receive timely and full recovery of GHG emission compliance costs from customers, then such costs could adversely impact the results of operations and cash flows. Significant reductions in demand for the Company's utility services as a result of increased costs or emissions limitations could also adversely impact the results of operations and cash flows.
The Company monitors, analyzes and reports GHG emissions from its other operations as required by applicable laws and regulations.
The Company will continue to monitor GHG regulations and their potential impact on operations.
Due to the uncertain availability of technologies to control GHG emissions and the unknown obligations that potential GHG emission legislation or regulations may create, the Company cannot determine the potential financial impact on its operations.
There have also been recent efforts to discourage the investment community from investing in equity and debt securities of companies engaged in fossil fuel related business and pressuring lenders to limit funding to such companies. Additionally, some insurance carriers have indicated an unwillingness to insure assets and operations related to certain fossil fuels. Although the
Company has not experienced difficulties in accessing the capital markets or insurance; such efforts, if successfully directed at the Company, could increase the costs of or access to capital and interfere with business operations and ability to make capital expenditures.
Other Risks
The Company's various businesses are seasonal and subject to weather conditions that can adversely affect the Company's operations, revenues and cash flows.
The Company's results of operations can be affected by changes in the weather. Weather conditions
influence the demand for electricity and natural gas and affect the price of energy commodities. Utility operations have historically generated lower revenues when weather conditions are cooler than normal in the summer and warmer than normal in the winter particularly in jurisdictions that do not have weather normalization mechanisms in place. Where weather normalization mechanisms are in place, there is no assurance the Company will continue to receive such regulatory protection from adverse weather in future rates.
MDU Resources Group, Inc. Form 10-K 25
Part
I
Adverse weather conditions, such as heavy or sustained rainfall or snowfall, storms, wind and colder weather may affect the demand for products and the ability to perform services at the construction businesses and affect ongoing operation and maintenance and construction activities for the electric and natural gas transmission and distribution businesses. In addition, severe weather can be destructive, causing outages and property damage, which could require additional remediation costs. The Company could also be impacted by drought conditions, which may restrict the availability of water supplies and inhibit the ability of the construction businesses to conduct operations. As a result,
unusual or adverse weather conditions could negatively affect the Company's results of operations, financial position and cash flows.
Competition exists in all of the Company's businesses.
The Company's businesses are subject to competition. Construction services' competition is based primarily on price and reputation for quality, safety and reliability. Construction materials products are marketed under highly competitive conditions and are subject to competitive forces such as price, service, delivery time and proximity to the customer. The electric utility and natural gas industries also experience competitive pressures as a result of consumer
demands, technological advances and other factors. The pipeline business competes with several pipelines for access to natural gas supplies and for transportation and storage business. New acquisition opportunities are subject to competitive bidding environments which impact prices the Company must pay to successfully acquire new properties to grow its business. The Company's failure to effectively compete could negatively affect the Company's results of operations, financial position and cash flows.
The Company's operations may be negatively affected if it is unable to obtain, develop and retain key
personnel and skilled labor forces.
The Company must attract, develop and retain executive officers and other professional, technical and skilled labor forces with the skills and experience necessary to successfully manage, operate and grow the Company's businesses. Competition for these employees is high, and in some cases competition for these employees is on a regional or national basis. At times of low unemployment or economic downturns, it can be difficult for the Company to attract and retain qualified and affordable personnel. A shortage in the supply of skilled personnel creates competitive hiring markets, increased labor expenses, decreased productivity and potentially lost business
opportunities to support the Company's operating and growth strategies. Additionally, if the Company is unable to hire employees with the requisite skills, the Company may be forced to incur significant training expenses. As a result, the Company's ability to maintain productivity, relationships with customers, competitive costs, and quality services is limited by the ability to employ, retain and train the necessary skilled personnel and could negatively affect the Company's results of operations, financial position and cash flows.
The
Company's construction materials and contracting and construction services businesses may be exposed to warranty claims.
The Company, particularly its construction businesses, may provide warranties guaranteeing the work performed against defects in workmanship and material. If warranty claims occur, they may require the Company to re-perform the services or to repair or replace the warranted item, at a cost to the Company and could also result in other damages if the Company is not able to adequately satisfy warranty obligations. In addition, the
Company may be required under contractual arrangements with customers to warrant any defects or failures in materials the Company purchased from third parties. While the Company generally requires suppliers to provide warranties that are consistent with those the Company provides to customers, if any of the suppliers default on their warranty obligations to the Company, the Company may nonetheless incur costs to repair or replace the defective materials. Costs incurred as a result of warranty claims could adversely affect the
Company's results of operations, financial condition and cash flows.
The Company is a holding company as a result of the Holding Company Reorganization in 2019. The Company's investments in its subsidiaries comprise the Company's primary assets. The
Company depends on earnings, cash flows and dividends from its subsidiaries to pay dividends on its common stock. Regulatory, contractual and legal limitations, as well as their capital requirements, affect the ability of the subsidiaries to pay dividends to the Company and thereby could restrict or influence the Company's ability or decision to pay dividends on its common stock, which could adversely affect the Company's stock price.
Costs related to obligations under MEPPs could have a material negative
effect on the Company's results of operations and cash flows.
Various operating subsidiaries of the Company participate in approximately 68 MEPPs for employees represented by certain unions. The Company is required to make contributions to these plans in amounts established under numerous collective bargaining agreements between the operating subsidiaries and those unions.
The Company may be
obligated to increase its contributions to underfunded plans that are classified as being in endangered, seriously endangered or critical status as defined by the Pension Protection Act of 2006. Plans classified as being in one of these statuses are required to adopt RPs or FIPs to improve their funded status through increased contributions, reduced benefits or a combination of the two. Based on available information, the Company believes that approximately 31 percent of the MEPPs to which it contributes are currently in endangered, seriously endangered or critical status.
The Company may also be required to increase its contributions to MEPPs if the other participating employers in such plans withdraw from the plans and are not able to contribute amounts sufficient
to fund the unfunded liabilities associated with their participation in the plans. The amount and timing of any increase in the Company's required contributions to MEPPs may depend upon one or more factors including the outcome of collective bargaining; actions taken by trustees who manage the plans; actions taken by the plans' other participating employers; the industry for which contributions are made; future determinations that additional plans reach endangered, seriously endangered or critical status; newly-enacted government laws or regulations and the actual return on assets held in the plans; among others. The Company could experience increased operating
26 MDU
Resources Group, Inc. Form 10-K
Part I
expenses as a result of required contributions to MEPPs, which could have an adverse effect on the Company's results of operations, financial position or cash flows.
In addition, pursuant to ERISA, as amended by MPPAA, the Company could incur a partial or complete withdrawal liability upon withdrawing from a plan, exiting a market in
which it does business with a union workforce or upon termination of a plan. The Company could also incur additional withdrawal liability if its withdrawal from a plan is determined by that plan to be part of a mass withdrawal.
Information technology disruptions or cyber-attacks could adversely impact the Company's operations.
The Company uses technology in substantially all aspects of its business operations and requires uninterrupted operation of information technology systems, including disaster recovery and backup systems and network infrastructure. While the Company
has policies, procedures and processes in place designed to strengthen and protect these systems, they may be vulnerable to failures or unauthorized access, due to hacking, human error, theft, sabotage, malicious software, acts of terrorism, acts of war, acts of nature or other causes. If these systems fail or become compromised, and they are not recovered in a timely manner, the Company may be unable to fulfill critical business functions. This may include interruption of electric generation, transmission and distribution facilities, natural gas storage and pipeline facilities and facilities for delivery of construction materials or other products and services, any of which could adversely affect the Company's reputation, business, cash flows and results of operations or subject the
Company to legal or regulatory liabilities and increased costs. Additionally, because electric generation and transmission systems and natural gas pipelines are part of interconnected systems with other operators’ facilities, a cyber-related disruption in another operator’s system could negatively impact the Company's business.
The Company’s accounting systems and its ability to collect information and invoice customers for products and services could be disrupted. If the Company’s operations are disrupted, it could result in decreased revenues or remediation costs that could adversely affect the Company's
results of operations and cash flows.
The Company is subject to cybersecurity and privacy laws and regulations of many government agencies, including FERC and NERC. NERC issues comprehensive regulations and standards surrounding the security of bulk power systems and continually updates these requirements, as well as establishing new requirements with which the utility industry must comply. As these regulations evolve, the Company may experience increased compliance costs and may be at higher risk for violating these standards. Experiencing a cybersecurity incident could cause the Company to be non-compliant with applicable laws and regulations, causing the
Company to incur costs related to legal claims or proceedings and regulatory fines or penalties.
The Company, through the ordinary course of business, requires access to sensitive customer, employee and Company data. While the Company has implemented extensive security measures, a breach of its systems could compromise sensitive data and could go unnoticed for some time. Such an event could result in negative publicity and reputational harm, remediation costs, legal claims and fines that could have an adverse effect on the Company's financial results. Third-party service providers that perform critical business functions for the
Company or have access to sensitive information within the Company also may be vulnerable to security breaches and information technology risks that could adversely affect the Company.
The Company’s information systems experience on-going and often sophisticated cyber-attacks by a variety of sources with the apparent aim to breach the Company's cyber-defenses. As cyber-attacks continue to increase in frequency and sophistication, the Company may be unable to prevent all such attacks in the future. The
Company is continuously reevaluating the need to upgrade and/or replace systems and network infrastructure. These upgrades and/or replacements could adversely impact operations by imposing substantial capital expenditures, creating delays or outages, or experiencing difficulties transitioning to new systems. Systems implementation disruption and any other information technology disruption, if not anticipated and appropriately mitigated, could adversely affect the Company.
General risk factors that could impact the Company's businesses.
The following are additional factors that should be considered for a better understanding of the risks to the Company.
These factors may negatively impact the Company's financial results in future periods.
•Acquisition, disposal and impairments of assets or facilities.
•Changes in present or prospective electric generation.
•Population decline and demographic patterns in the Company's areas of service.
•The cyclical nature of large construction projects at certain operations.
•Labor negotiations or disputes.
•Inability of
the contract counterparties to meet their contractual obligations.
•The inability to effectively integrate the operations and the internal controls of acquired companies.
Item 1B. Unresolved Staff Comments
The Company has no unresolved comments with the SEC.
MDU Resources Group, Inc.
Form 10-K 27
Part I
Item 3. Legal Proceedings
SEC regulations require the Company to disclose certain information about proceedings arising under federal, state or local environmental provisions if the Company reasonably believes that such proceedings may result in monetary sanctions above
a stated threshold. Pursuant to SEC regulations, the Company has adopted a threshold of $1.0 million for purposes of determining whether disclosure of any such proceedings is required.
For information regarding legal proceedings required by this item, see Item 8 - Note 21, which is incorporated herein by reference.
Item 4. Mine Safety Disclosures
For information regarding mine safety violations or other regulatory matters required by Section 1503(a) of the Dodd-Frank Act and Item 104 of Regulation S-K, see Exhibit 95
to this Form 10-K, which is incorporated herein by reference.
28 MDU Resources Group, Inc. Form 10-K
Part II
Item 5.
Market for the Registrant's Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities
The Company's common stock is listed on the New York Stock Exchange under the symbol "MDU."
The Company depends on earnings and dividends from its subsidiaries
to pay dividends on common stock. The Company has paid uninterrupted dividends to stockholders for 83 consecutive years with an increase in the payout amount for the last 30 consecutive years. The declaration and payment of dividends is at the sole discretion of the board of directors, subject to limitations imposed by the Company's credit agreements, federal and state laws, and applicable regulatory limitations. For more information on factors that may limit the Company's ability to pay dividends, see Item 8 - Note 12.
The following table includes information with respect to the Company's purchase
of equity securities:
ISSUER PURCHASES OF EQUITY SECURITIES
Period
(a) Total Number of Shares (or Units) Purchased (1)
(b) Average Price Paid per Share (or Unit)
(c) Total Number of Shares (or Units) Purchased as Part of Publicly Announced Plans or Programs (2)
(d) Maximum
Number (or Approximate Dollar Value) of Shares (or Units) that May Yet Be Purchased Under the Plans or Programs (2)
(1) Represents shares of common stock purchased on the open market in connection with annual stock grants made to the Company's
non-employee directors.
(2) Not applicable. The Company does not currently have in place any publicly announced plans or programs to purchase equity securities.
MDU Resources Group, Inc. Form 10-K 29
Part
II
Item 6. Selected Financial Data
2020
2019
2018
2017
2016
2015
Selected
Financial Data
Operating revenues (000's):
Electric
$
332,029
$
351,725
$
335,123
$
342,805
$
322,356
$
280,615
Natural
gas distribution
848,185
865,222
823,247
848,388
766,115
817,419
Pipeline
143,877
140,444
128,923
122,213
141,602
154,904
Construction
materials and contracting
2,178,002
2,190,717
1,925,854
1,812,529
1,874,270
1,904,282
Construction services
2,095,723
1,849,266
1,371,453
1,367,602
1,073,272
926,427
Other
11,903
16,551
11,259
7,874
8,643
9,191
Intersegment
eliminations
(76,969)
(77,149)
(64,307)
(58,060)
(57,430)
(78,786)
$
5,532,750
$
5,336,776
$
4,531,552
$
4,443,351
$
4,128,828
$
4,014,052
Operating
income (loss) (000's):
Electric
$
63,434
$
64,039
$
65,148
$
79,902
$
67,929
$
59,915
Natural
gas distribution
73,082
69,188
72,336
84,239
66,166
54,974
Pipeline
49,436
42,796
36,128
36,004
42,864
30,218
Construction
materials and contracting
214,498
179,955
141,426
143,230
178,753
148,312
Construction services
147,644
126,426
86,764
81,292
53,546
43,678
Other
(3,169)
(1,184)
(79)
(619)
(349)
(8,414)
Intersegment
eliminations
—
—
—
—
—
(2,942)
$
544,925
$
481,220
$
401,723
$
424,048
$
408,909
$
325,741
Earnings
(loss) on common stock (000's):
Electric
$
55,601
$
54,763
$
47,000
$
49,366
$
42,222
$
35,914
Natural
gas distribution
44,049
39,517
37,732
32,225
27,102
23,607
Pipeline
37,012
29,603
28,459
20,493
23,435
13,250
Construction
materials and contracting
147,325
120,371
92,647
123,398
102,687
89,096
Construction services
109,721
92,998
64,309
53,306
33,945
23,762
Other
(3,181)
(2,086)
(761)
(1,422)
(3,231)
(14,941)
Intersegment
eliminations
—
—
—
6,849
6,251
5,016
Earnings on common stock before income (loss) from discontinued operations
390,527
335,166
269,386
284,215
232,411
175,704
Income
(loss) from discontinued operations, net of tax*
(322)
287
2,932
(3,783)
(300,354)
(834,080)
Loss from discontinued operations attributable to noncontrolling interest
—
—
—
—
(131,691)
(35,256)
$
390,205
$
335,453
$
272,318
$
280,432
$
63,748
$
(623,120)
Earnings
per common share before discontinued operations - diluted
$
1.95
$
1.69
$
1.38
$
1.45
$
1.19
$
.90
Discontinued operations attributable to the Company, net
of tax
—
—
.01
(.02)
(.86)
(4.10)
$
1.95
$
1.69
$
1.39
$
1.43
$
.33
$
(3.20)
Common
Stock Statistics
Weighted average common shares outstanding - diluted (000's)
200,571
198,626
196,150
195,687
195,618
194,986
Dividends
declared per common share
$
.8350
$
.8150
$
.7950
$
.7750
$
.7550
$
.7350
Book value per common share
$
15.36
$
14.21
$
13.09
$
12.44
$
11.78
$
12.83
Market
price per common share (year end)
$
26.34
$
29.71
$
23.84
$
26.88
$
28.77
$
18.32
Market price ratios:
Dividend
payout**
43
%
48
%
58
%
53
%
63
%
82
%
Yield
3
%
3
%
3
%
3
%
3
%
4
%
Market
value as a percent of book value
171
%
209
%
182
%
216
%
244
%
143
%
* Reflects oil and natural gas properties noncash write-downs of $315.3 million (after tax) in 2015 and fair value impairments of assets held for sale of $157.8 million (after tax) and $475.4 million (after tax) in 2016 and 2015, respectively.
**Based
on continuing operations.
30 MDU Resources Group, Inc. Form 10-K
Part II
Item 6. Selected Financial Data (continued)
2020
2019
2018
2017
2016
2015
General
Total
assets (000's)
$
8,053,372
$
7,683,059
$
6,988,110
$
6,334,666
$
6,284,467
$
6,565,154
Total long-term debt (000's)
$
2,213,130
$
2,243,107
$
2,108,695
$
1,714,853
$
1,790,159
$
1,796,163
Capitalization
ratios:
Total equity
58
%
56
%
55
%
59
%
56
%
58
%
Total
debt
42
44
45
41
44
42
100
%
100
%
100
%
100
%
100
%
100
%
Electric
Retail
sales (thousand kWh)
3,204,523
3,314,307
3,354,401
3,306,470
3,258,537
3,316,017
Electric system summer and firm purchase contract ZRCs (Interconnected system)
553.2
591.3
574.5
553.1
559.7
547.3
Electric
system peak demand obligation, including firm purchase contracts, planning reserve margin requirement (Interconnected system)
531.4
537.2
537.2
530.2
559.7
547.3
All-time demand peak - kW (Interconnected system)
611,542
611,542
611,542
611,542
611,542
611,542
Electricity
produced (thousand kWh)
2,647,746
2,792,770
2,840,353
2,630,640
2,626,763
1,898,160
Electricity purchased (thousand kWh)
890,054
891,539
831,039
955,687
904,702
1,658,002
Average
cost of electric fuel and purchased power per kWh
$
.019
$
.023
$
.022
$
.022
$
.021
$
.024
Natural Gas Distribution
Retail
sales (Mdk)
114,543
123,675
112,566
112,551
99,296
95,559
Transportation sales (Mdk)
160,010
166,077
149,497
144,477
147,592
154,225
Pipeline
Transportation
(Mdk)
438,615
429,660
351,498
312,520
285,254
290,494
Gathering (Mdk)
8,611
13,900
14,882
16,064
20,049
33,441
Customer
natural gas storage balance (Mdk)
25,451
16,223
13,928
22,397
26,403
16,600
Construction Materials and Contracting
Sales
(000's):
Aggregates (tons)
30,949
32,314
29,795
28,213
27,580
26,959
Asphalt (tons)
7,202
6,707
6,838
6,237
7,203
6,705
Ready-mixed
concrete (cubic yards)
4,087
4,123
3,518
3,548
3,655
3,592
Aggregate reserves (000's tons)
1,104,887
1,054,186
1,014,431
965,036
989,084
1,022,513
MDU
Resources Group, Inc. Form 10-K 31
Part II
Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations
The Company focuses on infrastructure and is Building a Strong America® by providing essential products and services through its regulated energy delivery and construction materials and services businesses. The
Company and its employees work hard to keep the economy of the United States moving with the products and services provided, which include powering and connecting homes, factories, offices and stores; and building roads, highways, data infrastructure and airports.
The Company's two-platform business model, regulated energy delivery and construction materials and services, are each comprised of different operating segments. Most of these segments experience seasonality related to the industries in which they operate. The two-platform approach helps balance this seasonality and the risks associated with each type of industry. The Company is authorized to conduct business in 45 states and during peak times has over 15,600 employees. The
Company’s organic investments are strong drivers of high-quality earnings growth and continue to be an important part of the Company’s growth story. Management believes the Company is well positioned in the industries and markets in which it operates.
In March 2020, the World Health Organization declared the outbreak of COVID-19 a pandemic, and the President of the United States declared the COVID-19 outbreak as a national emergency. Most of the Company's products and services are considered essential to our country
and our communities; therefore, operations have generally been permitted to proceed with increased social distancing measures and hygiene practices for its employees. While the Company has experienced some inefficiency impacts, including operation suspensions and interruptions at some locations to carry out preventative measures or in response to instances of positive tests, the impacts have not been material. For more information on specific impacts to each of the Company's business segments, see the following discussions in each business segment's Outlook section.
In March 2020, the President of the United States signed into law the CARES Act in response to the COVID-19 pandemic. The CARES Act provided economic relief and stimulus to support the national economy
during the pandemic, including support for individuals and businesses affected by the pandemic and economic downturn. The CARES Act allowed businesses to defer payment of the employer portion of social security taxes incurred through the end of 2020. At December 31, 2020, the Company had deferred approximately $56.7 million in payroll taxes related to this provision. The Company is required to pay 50 percent of the payroll taxes deferred under this provision by the end of 2021 and the remaining balance by the end of 2022.
The Company evaluated its planned capital projects and delayed certain expenditures in 2020 to provide additional
financial flexibility and to ensure projects will provide acceptable returns on investment. In addition, the Company established a task force to monitor developments related to the pandemic and implemented procedures to protect employees. Many employees that have the capacity to work from home continue to do so as the Company has delayed return to work processes for certain office employees due to COVID-19 cases in some operating regions. The Company has also enacted additional physical and cybersecurity measures to safeguard systems for remote work locations.
Although there have been logistical and other challenges as a result of COVID-19, there were no material adverse impacts on
the Company's results of operations for the year ended December 31, 2020. The Company continues to adjust its business in response to the pandemic while positioning for an economic rebound and potential opportunities to enhance its competitive position. The situation surrounding COVID-19 remains fluid and the potential for a material adverse impact on the Company increases the longer the virus impacts the level of economic activity in the United States. Due to the uncertainty of the economic outlook resulting from the COVID-19 pandemic, the Company continues to monitor the situation closely.
For more information on the possible impacts, see Item 1A - Risk Factors.
32 MDU Resources Group, Inc. Form 10-K
Part II
Consolidated Earnings Overview
The following table summarizes the contribution
to the consolidated income by each of the Company's business segments.
Income (loss) from discontinued operations, net of tax
(.3)
.3
2.9
Net income
$
390.2
$
335.5
$
272.3
Earnings
per share - basic:
Income from continuing operations
$
1.95
$
1.69
$
1.38
Discontinued operations, net of tax
—
—
.01
Earnings
per share - basic
$
1.95
$
1.69
$
1.39
Earnings per share - diluted:
Income from continuing operations
$
1.95
$
1.69
$
1.38
Discontinued
operations, net of tax
—
—
.01
Earnings per share - diluted
$
1.95
$
1.69
$
1.39
2020 compared to 2019The Company's consolidated earnings increased $54.7 million
or 16 percent in 2020 as compared to 2019.
The Company's earnings were positively impacted by increased earnings across all of the Company's businesses in 2020. The construction materials and contracting business experienced an increase in gross margin, primarily resulting from favorable weather conditions and higher realized materials margins on asphalt and asphalt-related products and ready-mixed concrete, as well as most other product lines. The construction services business also experienced an increase in gross margin as a result of higher inside and outside specialty contracting workloads, partially due to the businesses acquired, as well as hospitality projects, high-tech projects and natural disaster recovery work. The pipeline business experienced increased
transportation volumes and revenues, largely related to organic growth projects, as well as higher storage-related revenues as a result of stronger demand for storage services. In addition, approved rate recovery positively impacted earnings at the electric and natural gas distribution businesses.
2019 compared to 2018The Company's consolidated earnings increased $63.2 million or 23 percent in 2019 as compared to 2018.
Positively impacting the Company's earnings was an increase in gross margin at the construction services business, largely resulting from higher inside and outside specialty contracting workloads. Also contributing to the increase in earnings was an increase in gross margin at the
construction materials and contracting business as a result of strong economic environments in certain states, as well as contributions from the businesses acquired and an increase in gains recognized on asset sales. The electric business also positively impacted earnings primarily due to approved rate relief in Montana and recovery of the investment in the BSSE project placed into service in the first quarter of 2019. Higher returns on the Company's benefit plan investments also increased earnings across all businesses. At the pipeline business, increased rates and volumes of natural gas being transported through its pipeline were mostly offset by the absence of a $4.2 million income tax benefit recorded in 2018 relating to the reversal of a regulatory liability recorded in 2017 based on a FERC final accounting order and higher depreciation, depletion and amortization expense.
A
discussion of key financial data from the Company's business segments follows.
Business Segment Financial and Operating Data
Following are key financial and operating data for each of the Company's business segments. Also included are highlights on key growth strategies, projections and certain assumptions for the Company and its subsidiaries and other matters of the
Company's business segments. Many of these highlighted points are "forward-looking statements." For more information, see Part I - Forward-Looking Statements. There is no assurance that the Company's projections, including estimates for growth and changes in earnings, will in fact be achieved. Please refer to assumptions contained in this section, as well as the various important factors listed in Item 1A - Risk Factors. Changes in such assumptions and factors could cause actual future results to differ materially from the Company's growth and earnings projections.
For information pertinent to various commitments and contingencies, see Item 8 - Notes to Consolidated Financial Statements. For a summary of the
Company's business segments, see Item 8 - Note 17.
MDU Resources Group, Inc. Form 10-K 33
Part II
Electric and Natural Gas Distribution
Strategy and challenges The electric
and natural gas distribution segments provide electric and natural gas distribution services to customers, as discussed in Items 1 and 2 - Business Properties. Both segments strive to be top performing utility companies measured by integrity, employee safety and satisfaction, customer service and shareholder return, while providing safe, environmentally friendly, reliable and competitively priced energy and related services to customers. The Company is focused on cultivating organic growth while managing operating costs and monitoring opportunities for these segments to retain, grow and expand their customer base through extensions of existing operations, including building and upgrading electric generation, transmission and distribution, and natural gas systems, and through selected acquisitions of companies and properties with similar operating and growth objectives at prices that will
provide stable cash flows and an opportunity to earn a competitive return on investment. The continued efforts to create operational improvements and efficiencies across both segments promotes the Company's business integration strategy. The primary factors that impact the results of these segments are the ability to earn authorized rates of return, the cost of natural gas, cost of electric fuel and purchased power, weather, competitive factors in the energy industry, population growth and economic conditions in the segments' service areas.
The electric and natural gas distribution segments are subject to extensive regulation in the jurisdictions where they conduct operations with respect to costs, timely recovery of investments and permitted returns on investment, as well as certain operational, environmental and system integrity regulations.
Legislative and regulatory initiatives to increase renewable energy resources and reduce GHG emissions could impact the price and demand for electricity and natural gas, as well as increase costs to produce electricity and natural gas. The segments continue to invest in facility upgrades to be in compliance with the existing and future regulations. To assist in the reduction of regulatory lag in obtaining revenue increases to align with increased investments, tracking mechanisms have been implemented in certain jurisdictions, as further discussed in Items 1 and 2 - Business Properties and Item 8 - Note 20.
In September 2019, the Pipeline and Hazardous Materials Safety Administration issued a rule for additional regulations to strengthen the safety of natural gas transmission and storage facilities and hazardous liquid pipelines. The natural gas segment has implemented procedure changes for the initial requirements and continues
to evaluate procedure changes necessary for the additional requirements effective July 1, 2021.
State implementation of pollution control plans to improve visibility at Class I areas, such as national parks, under the EPA's Regional Haze Rule could require the owners of Coyote Station to incur significant new costs. If the owners decide to incur such costs, the costs could, dependent on determination by state regulatory commissions on approval to recover such costs from customers, negatively impact the Company's results of operations, financial position and cash flows. The NDDEQ's state implementation plan is due to be submitted to the EPA by July 2021. The Company expects the NDDEQ to draft a state implementation
plan and share its controls selection with federal land managers of the National Park Service and the United States Fish and Wildlife Service in early 2021. Additionally, the Company is one of four owners of Coyote Station and cannot make a unilateral decision on the plant's future. The Company could be negatively impacted by the decisions of the other owners.
The electric and natural gas distribution segments are facing increased lead times on delivery of certain raw materials used in electric transmission and natural gas pipeline projects. Long lead times are attributable to increased demand for steel products from pipeline companies as they respond to the United States Department of Transportation Pipeline System Safety and Integrity Plan, as well as delays in
the manufacturing of electrical equipment as a result of the COVID-19 pandemic, including delays in trucking times and issuance of permits for large and heavy loads. The Company continues to monitor the material lead times and is working with manufacturers to proactively order such materials to help mitigate the risk of delays due to extended lead times.
The ability to grow through acquisitions is subject to significant competition and acquisition premiums. In addition, the ability of the segments to grow their service territory and customer base is affected by regulatory constraints, the economic environment of the markets served and competition from other energy providers and fuels. The construction of any new electric generating facilities, transmission lines and other service facilities is subject to increasing costs and lead times, extensive
permitting procedures, and federal and state legislative and regulatory initiatives, which will likely necessitate increases in electric energy prices.
Revenues are impacted by both customer growth and usage, the latter of which is primarily impacted by weather, as well as impacts associated with commercial and industrial slow-downs, including economic recessions, and energy efficiencies. Very cold winters increase demand for natural gas and to a lesser extent, electricity, while warmer than normal summers increase demand for electricity, especially among residential and commercial customers. Average consumption among both electric and natural gas customers has tended to decline as more efficient appliances and furnaces are installed, and as the Company has implemented conservation programs. Natural gas weather normalization and decoupling mechanisms
in certain jurisdictions have been implemented to largely mitigate the effect that would otherwise be caused by variations in volumes sold to these customers due to weather and changing consumption patterns on the Company's distribution margins, as further discussed in Items 1 and 2 - Business Properties.
34 MDU Resources Group, Inc. Form 10-K
Part II
Earnings
overview - The following information summarizes the performance of the electric segment.
Average
cost of electric fuel and purchased power per kWh
$
.019
$
.023
$
.022
Adjusted
gross margin is a non-GAAP financial measure. For additional information and reconciliation of the non-GAAP adjusted gross margin attributable to the electric segment, see the Non-GAAP Financial Measures section later in this Item.
2020 compared to 2019 Electric earnings increased $800,000 as a result of:
Adjusted gross margin: Comparable to the prior year. The adjusted gross margin was positively impacted by higher rates of $2.8 million, including approved rate relief resulting in $2.0 million additional revenue. These increases were offset by lower retail sales volumes of 3.3 percent across all customer classes due to warmer weather and slow-downs as a result of the COVID-19 pandemic.
Operation and maintenance: Decrease of $4.4 million, largely due to lower generation
station expenses of $3.5 million and lower payroll and other employee-related costs of approximately $1.5 million. Partially offsetting the decreases were increased bad debt expense of $500,000 as a result of the COVID-19 pandemic, as discussed later.
Depreciation, depletion and amortization: Increase of $4.3 million, largely from an increase in asset base driven by capital expenditures, which include transmission projects, and higher depreciation rates implemented from a Montana rate case of $1.2 million.
Taxes, other than income: Increase of $700,000, from higher property taxes in certain jurisdictions.
Other income: Increase of $3.8 million, largely attributable to an out-of-period adjustment of $2.5 million in the fourth quarter of 2020 related to previously overstated
benefit plan expense, as discussed in Item 8 - Note 1, and the absence of the write-down of a non-utility investment in the second quarter of 2019 for $1.2 million, as discussed in Item 8 - Note 8. Lower 2020 pension expense also contributed to the increase in other income.
Interest expense: Increase of $1.4 million driven by higher short-term debt balances.
Income tax benefit: Decrease of $1.0 million, largely due to higher income before income taxes.
2019 compared to 2018Electric earnings increased $7.8 million as a result of:
Adjusted gross margin: Increase of $10.8 million, primarily due to an increase in revenues. The revenue increase was driven by implemented regulatory
mechanisms, which include approved Montana interim and final rates and recovery of the investment in the BSSE project placed into service in the first quarter of 2019. Also contributing to the increase was the absence in 2019 of a transmission formula rate adjustment
MDU Resources Group, Inc. Form 10-K 35
Part II
recognized in the third quarter
of 2018 for decreased costs on the BSSE project. These increases were partially offset by lower retail sales volumes of 1.2 percent across all major customer classes.
Operation and maintenance: Increase of $2.7 million, primarily resulting from higher payroll-related costs, partially offset by lower material expenses across all locations.
Depreciation, depletion and amortization: Increase of $7.7 million as a result of increased property, plant and equipment balances including the BSSE project, as previously discussed, and other capital projects, as well as a reserve for certain costs related to the retirement of three aging coal-fired electric generating units, as discussed in Item 8 - Note 6, which is offset in income taxes.
Taxes, other than income: Increase of $1.6
million, primarily from higher property taxes in certain jurisdictions.
Other income: Increase of $2.2 million, largely the result of higher returns on the Company's benefit plan investments, partially offset by the write-down of a non-utility investment in the second quarter of 2019, as discussed in Item 8 - Note 8.
Interest expense: Decrease of $600,000 driven by higher AFUDC, which resulted in more interest being capitalized on regulated construction projects.
Income tax benefit: Increase of $6.2 million, largely due to increased production tax credits, as well as increased excess deferred tax amortization.
Earnings overview - The
following information summarizes the performance of the natural gas distribution segment.
Adjusted gross margin is a non-GAAP financial measure. For additional information and reconciliation of the non-GAAP adjusted gross margin attributable to the natural gas distribution segment, see the Non-GAAP Financial Measures
section later in this Item.
2020 compared to 2019 Natural gas distribution earnings increased $4.5 million as a result of:
Adjusted gross margin: Increase of $10.4 million, largely the result of $6.8 million in approved rate recovery in certain jurisdictions, higher basic service charges of $2.1 million due to customer growth of 2 percent and increased property tax tracker revenue of $1.7 million, which offsets the property tax expense below. Slightly offsetting the increases was a decrease in retail sales volumes of 7.4 percent across all customer classes due to warmer weather and slow-downs as a result of the COVID-19 pandemic, which was largely offset by weather normalization and decoupling mechanisms in certain jurisdictions.
Operation and maintenance: Increase of
$400,000, primarily related to increased contract services, largely $1.2 million for the write-off of an abandoned project in the third quarter of 2020, and increased software expenses. Partially offsetting the increase was lower employee-related costs of $1.6 million as a result of the COVID-19 pandemic.
Depreciation, depletion and amortization: Increase of $5.0 million, primarily from an increase in asset base driven by capital expenditures, which include system safety and reliability enhancements and other growth projects.
Taxes, other than income: Increase of $1.1 million due to higher property taxes in certain jurisdictions of $1.7 million, partially offset by lower payroll taxes.
Other income:
Increase of $6.3 million, largely driven by an out-of-period adjustment of $4.4 million in the fourth quarter of 2020 related to previously overstated benefit plan expenses, as discussed in Item 8 - Note 1, and lower 2020 benefit plan expenses of approximately $2.2 million. The absence of the write-down of a non-utility investment of approximately $800,000 in the second quarter of 2019, as discussed in Item 8 - Note 8, also contributed to the increase in other income. Partially offsetting the increases was a decrease in interest income of $1.5 million related to the recovery of purchased gas cost adjustment balances.
Interest expense: Increase of $1.3 million, primarily attributable to increased long-term debt balances, partially offset by lower short-term borrowings.
Income tax expense: Increase of $4.4 million, as a result of the increase
in income before taxes and permanent tax adjustments.
2019 compared to 2018 Natural gas distribution earnings increased $1.8 million as a result of:
Adjusted gross margin: Increase of $17.4 million, primarily driven by an increase in retail sales volumes of 9.9 percent related to all customer classes due to colder weather, partially offset by weather normalization and conservation adjustments in certain jurisdictions, and approved rate recovery in certain jurisdictions. The adjusted gross margin was also positively impacted by higher rate realization due to higher conservation revenue, which offsets the conservation expense in operation and maintenance expense.
Operation and maintenance: Increase of $11.6 million, largely related to higher payroll-related costs, as well
as higher conservation expenses being recovered in revenue. The increase was partially offset by lower contract services, which includes the absence of the prior year's recognition of a non-recurring expense related to the approved WUTC general rate case settlement in the second quarter 2018.
Depreciation, depletion and amortization: Increase of $7.1 million, primarily as a result of increased property, plant and equipment balances.
Taxes, other than income: Increase of $1.8 million due to higher property taxes in certain jurisdictions and increased payroll taxes.
Other income: Increase of $7.0 million, largely resulting from higher returns on the
Company's benefit plan investments and increased interest income related to higher gas costs to be collected from customers. Partially offsetting these increases was a write-down of a non-utility investment in the second quarter of 2019, as discussed in Item 8 - Note 8.
Interest expense: Increase of $4.8 million, largely resulting from increased debt balances to finance higher gas costs to be collected from customers.
Income tax expense: Decrease of $2.7 million, largely due to increased permanent tax benefits related to the Company's benefit plan investments.
MDU
Resources Group, Inc. Form 10-K 37
Part II
OutlookThe Company continues to assess the impacts of the COVID-19 pandemic on its operations and is committed to providing safe and reliable service while ensuring the health and safety of its employees, customers and the communities in which it operates. In response to the pandemic, the Company instituted certain measures
to help protect its employees from exposure to COVID-19 and to curb potential spread of the virus in customer homes and facilities, including suspension of disconnects due to nonpayment of bills. The Company also waived late payment fees effective April 1, 2020, to help customers experiencing financial hardships. As a consequence of the suspended disconnects and waived late fees, the Company's cash flows and collection of receivables have been affected. The Company reinstated disconnects and late payment fees in five of its eight states effective September 1, 2020, and the
Company reinstated disconnects and late payment fees to certain customer classes in another two states effective January 1, 2021. The Company has experienced some impacts to its commercial and industrial electric and natural gas loads associated with reduced economic activity due to the COVID-19 pandemic and oil price impacts, as further discussed below. The Company expects this downward trend on demand to continue throughout the pandemic. The Company temporarily implemented cost containment measures in response to the COVID-19 pandemic, including reduced employee travel and temporary delays in training for employees, as well as delays in filling open positions and contract
work. The Company has filed requests for the use of deferred accounting for costs related to the COVID-19 pandemic in most of the jurisdictions in which it operates; the Company has deferred an immaterial amount related to the pandemic to date. The Company's outstanding filings by jurisdiction related to the COVID-19 pandemic are discussed in Item 8 - Note 20.
The Company expects these segments will grow rate base by approximately 5 percent annually over the next five years on a compound basis. Operations are spread across eight states where the
Company expects customer growth to be higher than the national average. In 2020 and 2019, these segments experienced retail customer growth of approximately 1.8 percent each year and expects customer growth to continue to average 1 percent to 2 percent per year. This customer growth, along with system upgrades and replacements needed to supply safe and reliable service, will require investments in new and replacement electric and natural gas systems.
These segments are exposed to energy price volatility. Rate schedules in the jurisdictions in which the Company's natural gas distribution segment operates contain clauses that permit the Company to file for rate adjustments for changes in the cost of purchased gas. Although changes in the price of natural gas are
passed through to customers and have minimal impact on the Company's earnings, the natural gas distribution segment's customers benefit from lower natural gas prices through the Company's utilization of storage and fixed price contracts. Additionally, the Company has implemented risk mitigation measures to minimize the price volatility associated with natural gas costs through derivative contracts at Cascade. For further discussion on the Company's derivative instruments,
see Item 8 - Note 2. Demand for the Company's regulated energy delivery services could be impacted by reduced oil and natural gas exploration and production activity. The Company continues to monitor natural gas prices, as well as the oil and natural gas production levels.
In February 2019, the Company announced that it intends to retire three aging coal-fired electric generating units, resulting from the Company's analysis showing that the plants are no longer expected to be cost competitive for customers. The retirements are expected to be in March 2021 for Unit 1 at Lewis & Clark Station in Sidney,
Montana, and in early 2022 for Units 1 and 2 at Heskett Station near Mandan, North Dakota. In addition, the Company announced that it intends to construct Heskett Unit 4, an 88-MW simple-cycle natural gas-fired combustion turbine peaking unit at the existing Heskett Station near Mandan, North Dakota. Heskett Unit 4 production costs coupled with the MISO market purchases are expected to be about half the total cost of continuing to run the coal-fired electric generating units at Heskett and Lewis & Clark stations. Heskett Unit 4 was included in the Company's integrated resource plan submitted to the NDPSC in July 2019. On August 28, 2019, the Company filed for an advanced
determination of prudence with the NDPSC for Heskett Unit 4. This request was approved by the NDPSC on August 5, 2020. Heskett Unit 4 is expected to be placed into service in 2023. The Company filed, and the commissions approved, requests with the NDPSC, MTPSC and SDPUC for the usage of deferred accounting for the costs related to the retirement of Unit 1 at Lewis & Clark Station and Units 1 and 2 at Heskett Station.
In December 2020, the governor of Washington outlined a climate policy package that included House Bill 1084, which would eliminate all onsite fossil fuel emissions in new buildings by 2030 and eliminate fossil fuels from existing buildings by 2050, among other things. A public hearing on House Bill 1084 was held February 17, 2021,
in the House Committee on Appropriations. The Company is monitoring the status of the proposed legislation.
The Company continues to be focused on the regulatory recovery of its investments by filing for rate adjustments to seek recovery of operating costs and capital investments, as well as reasonable returns as allowed by regulators. The Company's most recent cases by jurisdiction are discussed in Item 8 - Note 20.
38 MDU Resources Group, Inc.
Form 10-K
Part II
Pipeline
Strategy and challenges The pipeline segment provides natural gas transportation, underground storage and energy-related services, as discussed in Items 1 and 2 - Business Properties. The segment focuses on utilizing its extensive expertise in the design, construction and operation of energy infrastructure and related services to increase market share and profitability through optimization
of existing operations, organic growth and investments in energy-related assets within or in close proximity to its current operating areas. The segment focuses on the continual safety and reliability of its systems, which entails building, operating and maintaining safe natural gas pipelines and facilities. The segment continues to evaluate growth opportunities including the expansion of natural gas facilities; incremental pipeline projects; and expansion of energy-related services leveraging on its core competencies. In support of this strategy, the Company completed and placed into service the following organic growth projects in 2020 and 2019:
•In September 2020 and November 2019, Phase II and Phase I, respectively, of the Line Section 22 Expansion project in the Billings, Montana, area. The total project increased
capacity by 22.5 MMcf per day.
•In February 2020, the Demicks Lake Expansion project in McKenzie County, North Dakota, increased capacity by 175 MMcf per day.
•In September 2019, the Demicks Lake project in McKenzie County, North Dakota, increased capacity by 175 MMcf per day.
The segment is exposed to energy price volatility which is impacted by the fluctuations in pricing, production and basis differentials of the energy market's commodities. Legislative and regulatory initiatives to increase pipeline safety regulations and reduce methane emissions could also impact the price and demand for natural gas.
The segment regularly experiences extended lead times on raw materials that are critical to the segment's construction and maintenance work. Long
lead times on materials could delay maintenance work and project construction potentially causing lost revenues and/or increased costs. The Company continues to proactively monitor and plan for the material lead times, as well as work with manufacturers and suppliers to help mitigate the risk of delays due to extended lead times.
The pipeline segment is subject to extensive regulation including certain operational, environmental and system integrity regulations, as well as various permit terms and operational compliance conditions. In September 2019, the Pipeline and Hazardous Materials Safety Administration issued a rule for additional regulations to strengthen the safety of natural gas transmission and storage facilities and hazardous liquid pipelines. The segment has implemented procedure changes for the initial requirements and continues to
evaluate procedure changes and implementation of physical modifications to existing facilities necessary for additional requirements effective July 1, 2021. The segment reviews and secures existing permits and easements, as well as new permits and easements as necessary, to meet current demand and future growth opportunities on an ongoing basis. Groups opposing pipelines could also cause negative impacts on the segment with increased costs, potential delays to project completion or cancellation of prospective projects.
The segment focuses on the recruitment and retention of a skilled workforce to remain competitive and provide services to its customers. The industry in which it operates relies on a skilled workforce to construct energy infrastructure and operate existing infrastructure in a safe manner. A shortage of skilled personnel can create a competitive labor market which
could increase costs incurred by the segment. Competition from other pipeline companies can also have a negative impact on the segment.
Earnings overview - The following information summarizes the performance of the pipeline segment.
2020 compared to 2019 Pipeline earnings increased $7.4 million as a result of:
Revenues: Increase of $3.5 million, largely attributable to increased transportation volumes and demand revenue of $6.2 million
largely from organic growth projects, as previously discussed, and increased storage-related revenues of $4.6 million as a result of stronger demand for storage services. Also contributing to the increase was additional revenues of $2.4 million primarily from increased rates effective May 1, 2019, due to the FERC rate case finalized in September 2019. These increases were partially offset by lower non-regulated project revenues of $5.3 million and lower volumes associated with the sale of the Company's natural gas gathering assets in 2020, as discussed later, and lower gathering rates resulting in a decrease in revenues of $4.3 million.
Operation and maintenance: Decrease of $3.2 million, primarily from decreased non-regulated project costs of $3.7 million associated with
lower non-regulated project revenue and $1.5 million gain on the sale of the Company's non-regulated natural gas gathering assets in 2020, as discussed later, partially offset by higher payroll-related costs.
Depreciation, depletion and amortization: Increase of $500,000, primarily due to additional expense of $1.3 million associated with increased property, plant and equipment balances as a result of organic growth projects that have been placed into service, and higher depreciation rates effective May 1, 2019, due to the FERC rate case finalized in September 2019. The sale of the Company's natural gas gathering assets in 2020, as discussed later, reduced the increases by $1.5 million.
Taxes,
other than income: Decrease of $400,000 driven by the sale of the Company's natural gas gathering assets, partially offset by higher property taxes in certain jurisdictions of $300,000.
Other income: Increase of $1.7 million, as a result of higher AFUDC of $1.1 million, a positive impact of $700,000 related to the sale of the Company's regulated gathering assets and an out-of-period adjustment of $500,000 in the fourth quarter of 2020 related to previously overstated benefit plan expense, as discussed in Item 8 - Note 1. Partially offsetting these increases was the write-off of unrecovered gas costs and project expenses of $1.2 million.
Interest expense:
Increase of $400,000, largely resulting from higher debt balances to finance organic growth projects, as previously discussed.
Income tax expense: Increase of $500,000, directly resulting from an increase in income before taxes, largely offset by the reversal of excess deferred taxes of $1.5 million associated with the sale of the Company's regulated natural gas gathering assets.
2019 compared to 2018 Pipeline earnings increased $1.1 million as a result of:
Revenues: Increase of $11.5 million, largely attributable to increased volumes of natural gas transported through its system as a result of organic growth projects, as previously discussed, and increased rates effective May
1, 2019, due to the FERC rate case finalized in September 2019.
Operation and maintenance: Increase of $900,000, primarily from higher payroll-related costs and materials costs.
Depreciation, depletion and amortization: Increase of $3.3 million, primarily due to increased property, plant and equipment balances, largely the result of organic growth projects that have been placed into service, and higher depreciation rates effective May 1, 2019, due to the FERC rate case finalized in September 2019.
Taxes, other than income: Increase of $600,000 driven by higher property taxes in certain jurisdictions.
Other income: Comparable to the prior year.
Interest
expense: Increase of $1.3 million, largely resulting from higher debt balances to finance organic growth projects, as previously discussed.
Income tax expense: Increase of $4.5 million, primarily driven by the absence in 2019 of a $4.2 million income tax benefit recorded in 2018 related to the reversal of a regulatory liability recorded in 2017 based on a FERC final accounting order issued.
OutlookThe Company continues to successfully manage the impacts of the COVID-19 pandemic on its operations and is committed to providing safe, reliable and compliant service while ensuring the health and safety of its employees, customers and the communities in which it operates. The
Company experienced minor delays on capital and maintenance projects during the first quarter of 2020 but resumed project activities in the second quarter of 2020. Work has progressed on these projects as scheduled through the fourth quarter of 2020. The Company does not expect delays to its regulatory filings due to the pandemic.
The Company has continued to experience the effect of associated natural gas production in the Bakken, which has provided opportunities for organic growth projects and increased demand. The completion of organic growth projects has contributed to the increased volumes of natural gas the Company transports through its system. Reduced global oil demand
due to the COVID-19 pandemic and disagreements in oil supply levels between the Organization of the Petroleum Exporting Countries and other countries led to record low oil prices during the first quarter of 2020;
40 MDU Resources Group, Inc. Form 10-K
Part II
however, oil prices started to recover after the first quarter of 2020 as states and other
countries started to reopen. Although low oil prices have slowed drilling activities and led to the shut-in of certain wells, producers continue to bring wells back online and the Company continues to focus on growth and improving existing operations through organic projects in all areas in which it operates. The national record levels of natural gas supply over the last few years have moderated the need for storage services and put downward pressure on natural gas prices and minimized price volatility. While the Company believes there will continue to be varying pressures on natural gas production levels and prices due to these circumstances, low natural gas prices provide growth opportunity for industrial supply related projects and seasonal pricing differentials provide opportunities for storage services.
In January 2019, the Company announced the North Bakken Expansion project, which includes construction of a new pipeline, compression and ancillary facilities to transport natural gas from core Bakken production areas near Tioga, North Dakota, to a new connection with Northern Border Pipeline in McKenzie County, North Dakota. Construction is expected to begin in the second quarter of 2021 with an estimated in-service date late in 2021, which is dependent on regulatory and environmental permitting. On February 14, 2020, the Company filed with the FERC its application for this project. On July 28, 2020, the
Company filed an amendment to its application with the FERC reflecting a decrease to the design capacity from 350 MMcf per day to 250 MMcf per day by reducing compression due to delays in forecasted growth levels of natural gas production in the Bakken region. Further, as a result of the forecasted Bakken oil and associated natural gas production delays driven by COVID-19 pandemic-related demand decreases and commodity price impacts, the Company negotiated adjustments to certain long-term customer commitments. A portion of the first-year committed volumes have been delayed one year and, through a combination of rate, volume and term adjustments, the overall project return profile remains unchanged and is expected to be accretive to earnings of the Company. These long-term take or pay customer contracts
support the project at a design capacity of 250 MMcf per day, which can be readily expanded when forecasted growth levels rebound. On December 17, 2020, the FERC issued its environment assessment for the project. FERC approval of the project is anticipated in early 2021.
In December 2019, the Company entered into a purchase and sale agreement to divest of the Company's regulated natural gas gathering assets located in Montana and North Dakota, which included approximately 400 miles of natural gas gathering pipelines and associated compression and ancillary facilities. On January 8, 2020, the
Company filed an application with the FERC to authorize abandonment by sale of the assets and received FERC approval on April 2, 2020. The sale closed in April 2020 with an effective date of January 1, 2020. Pursuant to the FERC's approval of the abandonment by sale, the proposed accounting treatment was filed with the FERC in October 2020 and approved in November 2020.
In October 2020, the Company entered into a purchase and sale agreement to divest of the Company's non-regulated natural gas gathering assets located in northern Montana, which included approximately 800 miles of natural gas gathering pipelines and associated compression and ancillary facilities.
The sale closed in November 2020 with an effective date of December 1, 2020. With the completion of this sale, the Company has exited the natural gas gathering business.
Construction Materials and Contracting
Strategy and challengesThe construction materials and contracting segment provides an integrated set of aggregate-based construction services, as discussed in Items 1 and 2 - Business Properties. The segment focuses on high-growth strategic markets located near major transportation corridors and desirable mid-sized metropolitan areas; strengthening the long-term, strategic aggregate reserve position
through available purchase and/or lease opportunities; enhancing profitability through cost containment, margin discipline and vertical integration of the segment's operations; development and recruitment of talented employees; and continued growth through organic and acquisition opportunities.
A key element of the Company's long-term strategy for this business is to further expand its market presence in the higher-margin materials business (rock, sand, gravel, liquid asphalt, asphalt concrete, ready-mixed concrete and related products), complementing and expanding on the segment's expertise. The Company's continued acquisition activity supports this strategy.
As one of the country's largest sand and gravel producers,
the segment continues to strategically manage its approximately 1.1 billion tons of aggregate reserves in all its markets, as well as take further advantage of being vertically integrated. The segment's vertical integration allows the segment to manage operations from aggregate mining to final lay-down of concrete and asphalt, with control of and access to permitted aggregate reserves being significant. The Company's aggregate reserves are naturally declining and as a result, the Company seeks acquisition opportunities to replace the reserves. In the fourth quarter of 2020, the Company acquired the assets of McMurry Ready-Mix Co., an aggregates and concrete supplier located in Casper, Wyoming. The acquisition included nearly
100 million tons of aggregate reserves. In the first quarter of 2019, the Company purchased additional aggregate deposits in Texas that were estimated to contain a 40-year supply of high-quality aggregates for projected local market needs. Also during 2019, the Company increased aggregate reserves by approximately 40 million tons largely due to strategic asset purchases.
The construction materials and contracting segment faces challenges that are not under the direct control of the business. The segment operates in geographically diverse and highly competitive markets. Competition can put negative pressure on the segment's operating margins. The segment is also subject to volatility in the cost of raw materials such as diesel fuel, gasoline, liquid asphalt, cement
and steel. Such volatility can have an impact on the segment's margins, including fixed-price construction contracts that are particularly vulnerable to the volatility of energy and material prices. Other variables that can impact the segment's margins include adverse weather conditions, the timing of project starts or completion and declines or delays in new and existing projects due to the cyclical nature of the construction industry and governmental infrastructure spending. Accordingly, operating results in any particular period may not be indicative of the results that can be expected for any other period.
MDU Resources Group, Inc.
Form 10-K 41
Part II
The segment also faces challenges in the recruitment and retention of employees. Trends in the labor market include an aging workforce and availability issues. The segment continues to face increasing pressure to control costs, as well as recruit and train a skilled workforce to meet the needs of increasing demand and seasonal work.
Earnings overview - The following information summarizes the performance of the construction materials and contracting segment.
2020 compared to 2019 Construction materials and contracting's earnings increased $26.9 million as a result of:
Revenues: Decrease of $12.7 million driven by lower contracting revenues partially due to lower materials pricing as a result of decreased energy-related costs. This decrease was offset in part by higher material sales on most product lines due to an early start to the season, favorable weather conditions in certain regions and additional revenues associated with the businesses acquired.
Gross
margin: Increase of $40.1 million, largely resulting from higher material revenues and margins and higher contracting margins. Asphalt and asphalt-related product margins increased $21.3 million overall. Strong pricing for ready-mixed concrete in most markets resulted in 1.9 percent higher margins. Contracting bid margins positively impacted gross margin by $6.5 million partially resulting from lower direct costs associated with having a longer construction season due to favorable weather conditions. The Company also benefited across all product lines from lower fuel costs. Partially offsetting these increases was lower gains on asset sales in certain regions of approximately $6.8 million.
Selling, general and administrative expense: Increase of $5.6 million, primarily related to higher payroll-related
costs of $2.2 million and increased amortization of intangible assets associated with the businesses acquired.
Other income: Decrease of $800,000, largely the result of an out-of-period adjustment to benefit expense in the fourth quarter of 2020, as discussed in Item 8 - Note 1.
Interest expense: Decrease of $3.2 million, from lower average debt balances in 2020 along with lower average interest rates.
Income tax expense: Increase of $10.0 million directly resulting from an increase in income before taxes.
2019 compared to 2018Construction materials and contracting's earnings increased $27.8 million as a result of:
Revenues: Increase
of $264.8 million driven by higher contracting services and material sales due to strong economic environments in certain states, as well as additional material volumes associated with the businesses acquired.
42 MDU Resources Group, Inc. Form 10-K
Part II
Gross margin: Increase of $48.5 million, largely resulting from higher
revenues due to strong economic environments in certain states, as previously discussed, higher contracting bid margins and higher realized material prices. Also contributing to the increased gross margin was an increase in gains on asset sales in certain regions of approximately $7.5 million.
Selling, general and administrative expense: Increase of $9.9 million, primarily related to the businesses acquired and higher payroll-related costs.
Other income (expense): Increase of $4.7 million, largely the result of higher returns on the Company's benefit plan investments.
Interest expense: Increase of $6.5 million, largely resulting from higher debt balances as a result of recent acquisitions,
capital expenditures and higher average interest rates.
Income tax expense: Increase of $9.0 million directly resulting from an increase in income before taxes.
OutlookThe Company continues to assess the impacts of the COVID-19 pandemic on its operations and is committed to the health and safety of its employees, customers and the communities in which it operates. The Company has implemented safety and social distancing measures for its employees that are not able to work from home and has experienced some inefficiencies and additional costs in relation to these measures but, for the most part, has been able to continue business processes with minimal
interruptions. The Company also continues to monitor job progress and service work and at this time has not experienced significant delays, cancellations or disruptions due to the pandemic. The Company will continue to monitor the demand for construction materials and contracting services as such services may be reduced by recessionary impacts of the pandemic as the traditional customers for these services reduce capital expenditures. State and local mandates were issued in response to the COVID-19 pandemic requiring individuals to stay in place, leading to a reduction in fuel consumption in the United States, which directly reduces fuel tax collections. In addition, states, cities and counties across the country are experiencing low sales tax and other revenues as a result of the COVID-19 pandemic. The
reduction in tax collections may impact funds available for public infrastructure projects, which in turn could have a material adverse impact on the Company's results of operations, financial position and cash flows. Meanwhile, a comprehensive infrastructure funding program, if adopted, by the United States Congress could positively impact the segment.
The segment's vertically integrated aggregate-based business model provides the Company with the ability to capture margin throughout the sales delivery process. The aggregate products are sold internally and externally for use in other products such as ready-mixed concrete, asphaltic concrete and public and private construction markets. The contracting services and construction materials are sold in connection with
street, highway and other public infrastructure projects, as well as private commercial and residential development projects. The public infrastructure projects have traditionally been more stable markets as public funding is more secure during periods of economic decline. The public projects are, however, dependent on federal and state funding such as appropriations to the Federal Highway Administration. Spending on private development is highly dependent on both local and national economic cycles, providing additional sales during times of strong economic cycles.
During 2020 and 2019, the Company made strategic asset purchases and completed several acquisitions that support the Company's long-term strategy to expand its market presence. In the first quarter of
2020, the Company acquired the assets of Oldcastle Infrastructure Spokane, a prestressed-concrete business located in Spokane, Washington. In the fourth quarter of 2020, the Company acquired the assets of McMurry Ready-Mix Co., an aggregates and concrete supplier located in Casper, Wyoming. The Company continues to evaluate additional acquisition opportunities. For more information on the Company's business combinations, see Item 8 - Note 4.
The construction materials and contracting segment's backlog remained strong at December 31, 2020, at $673 million,
which was comparable to backlog at December 31, 2019, of $693 million. A significant portion of the Company's backlog relates to street and highway construction. The Company expects to complete a significant amount of backlog at December 31, 2020, during the next 12 months.
Construction Services
Strategy and challenges The construction services segment provides inside and outside specialty contracting, as discussed in Items 1 and 2 - Business Properties. The construction services segment focuses
on safely executing projects; providing a superior return on investment by building new and strengthening existing customer relationships; ensuring quality service; effectively controlling costs; retaining, developing and recruiting talented employees; growing through organic and acquisition opportunities; and focusing efforts on projects that will permit higher margins while properly managing risk. The growth experienced by the segment in recent years is due in part to its ability to support national customers in most of the regions in which it operates.
The construction services segment faces challenges in the highly competitive markets in which it operates. Competitive pricing environments, project delays, changes in management's estimates of variable consideration and the effects from restrictive regulatory requirements have negatively impacted revenues and margins in the past and could affect revenues and margins in the
future. Additionally, margins may be negatively impacted on a quarterly basis due to adverse weather conditions, as well as timing of project starts or completions; disruptions to the supply chain due to transportation delays, travel restrictions, raw material cost increases and shortages and closures of businesses or facilities; declines or delays in new projects due to the cyclical nature of the construction industry; and other factors. These challenges may also impact the risk of loss on certain projects. Accordingly, operating results in any particular period may not be indicative of the results that can be expected for any other period.
The need to ensure available specialized labor resources for projects also drives strategic relationships with customers and project margins. These trends include an aging workforce and labor availability issues, increasing pressure to reduce costs and improve reliability, and increasing
duration
MDU Resources Group, Inc. Form 10-K 43
Part II
and complexity of customer capital programs. Due to these and other factors, the Company believes overall customer and competitor demand for labor resources will continue to increase, possibly surpassing the
supply of industry resources.
Earnings overview - The following information summarizes the performance of the construction services segment.
2020 compared to 2019Construction services
earnings increased $16.7 million as a result of:
Revenues: Increase of $246.4 million, primarily resulting from higher inside and outside specialty contracting workloads. Inside workloads contributed $127.2 million, or 10.0 percent more compared to 2019, largely from higher revenues of $71.4 million due to the addition of Perlectric, Inc. and increased customer demand for high-tech, hospitality and industrial projects. Outside workloads contributed $108.0 million, or 18.1 percent more compared to 2019, as a result of strong demand for utility projects including storm-related power line repair and wildfire restoration work.
Gross margin: Increase of $38.2 million, primarily from the higher volume of work resulting in an increase in revenues, as previously discussed, partially offset by an increase in operation and maintenance expense
as a direct result of the expenses related to the increased workloads.
Selling, general and administrative expense: Increase of $17.0 million, largely from increased costs of $8.3 million associated with the addition of PerLectric, Inc. operations, allowance for uncollectible accounts of $3.6 million, payroll-related costs of $3.1 million and office expenses.
Other income: Comparable to the prior year.
Interest expense: Decrease of $1.2 million, related to lower debt balances due to lower working capital needs as a result of payroll tax deferrals and increased cash collections.
Income tax expense: Increase of $5.8 million, directly resulting from an increase in income before taxes.
2019
compared to 2018 Construction services earnings increased $28.7 million as a result of:
Revenues: Increase of $477.8 million, largely resulting from higher inside specialty contracting workloads from an increase in customer demand for hospitality, data center and high-tech projects. Also contributing to the increase was higher outside specialty contracting workloads, primarily resulting from increased utility customer demand.
Gross margin: Increase of $55.3 million, primarily due to the higher volume of work resulting in an increase in revenues, as previously discussed, partially offset by an increase in operation and maintenance expense as a direct result of the increased workloads.
Selling, general and administrative expense: Increase of $15.7
million, resulting from increased payroll-related costs, as well as higher office expense and outside professional service costs.
Other income: Increase of $800,000, largely resulting from higher returns on the Company's benefit plan investments.
Interest expense: Increase of $1.7 million, related to higher debt balances as a result of additional working capital needs from the increase in contracting workloads in 2019.
44 MDU Resources Group, Inc. Form 10-K
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II
Income tax expense: Increase of $10.0 million, directly resulting from an increase in income before taxes.
OutlookThe Company continues to assess the impacts of the COVID-19 pandemic on its operations and is committed to the health and safety of its employees, customers and the communities in which it operates. The Company has implemented safety and social distancing measures for its employees that are not able to work from home and has experienced some inefficiencies in relation
to these measures but, for the most part, has been able to continue business processes. The Company continues to bid and be awarded work despite the challenging economic environment, as evidenced by the strong backlog for the segment, as further discussed below. The Company also continues to monitor job progress and service work and has experienced some delays, cancellations and disruptions due to the pandemic. The Company will continue to monitor the demand for construction services as such services may be reduced by recessionary impacts of the pandemic as the traditional customers for these services reduce capital expenditures.
The
Company continues to have bidding opportunities for both inside and outside specialty contracting work in 2021. Although bidding remains highly competitive in all areas, the Company expects the segment's skilled workforce, quality of service and effective cost management will continue to provide a benefit in securing and executing profitable projects.
The construction services segment's backlog at December 31 was as follows:
2020
2019
(In
millions)
Inside specialty contracting
$
1,059
$
908
Outside specialty contracting
214
236
$
1,273
$
1,144
The increase in backlog at December 31,
2020, as compared to backlog at December 31, 2019, was largely attributable to the new project opportunities that the Company continues to be awarded across its diverse operations, particularly inside specialty electrical and mechanical contracting in the hospitality, high-tech and public industries. The Company's outside power, communications and natural gas specialty contracting also have a high volume of available work. The Company expects to complete a significant amount of the backlog at December 31, 2020, during the next 12 months. Additionally, the
Company continues to further evaluate potential acquisition opportunities that would be accretive to earnings of the Company and continue to grow the Company's backlog.
In support of the Company's strategic plan to grow through acquisitions, the Company acquired PerLectric, Inc., an electrical construction company in Fairfax, Virginia, in the first quarter of 2020. For more information on the Company's business combinations, see Item 8 - Note 4.
Included in Other is insurance activity at the Company's captive insurer and general and administrative costs and interest expense previously allocated to the exploration and production and refining businesses that do not meet the criteria for income (loss) from discontinued operations.
Other was negatively impacted in 2020 as a result of higher insurance claims as compared to 2019, whereas 2019 had higher insurance premiums which increased both operating revenues and operation and maintenance expense.
MDU
Resources Group, Inc. Form 10-K 45
Part II
Intersegment Transactions
Amounts presented in the preceding tables will not agree with the Consolidated Statements of Income due to the Company's elimination of intersegment transactions. The amounts related to these items were as follows:
For more information on intersegment eliminations, see Item 8 - Note 17.
Liquidity and Capital Commitments
At
December 31, 2020, the Company had cash and cash equivalents of $59.6 million and available borrowing capacity of $736.3 million under the outstanding credit facilities of the Company's subsidiaries. During the first quarter of 2020, short-term capital markets were disrupted as a result of the COVID-19 pandemic. Consequently, the Company temporarily borrowed under its revolving credit agreements in addition to accessing the commercial paper markets and maintained higher than normal cash balances to ensure liquidity during this volatile period. At December 31,
2020, all borrowings under the revolving credit agreements for Montana-Dakota and Centennial had been repaid. The Company expects to meet its obligations for debt maturing within 12 months and its other operating and capital requirements from various sources, including internally generated funds; credit facilities and commercial paper of the Company's subsidiaries, as described later in Capital resources; and the issuance of debt and equity securities if necessary.
Cash flows
Operating activities
The changes in cash flows from operating activities generally follow the results of operations as discussed in Business Segment Financial and Operating Data and are also affected by changes in working capital. Changes in cash flows for discontinued operations are related to the Company's former exploration and production and refining businesses.
Cash flows provided by operating activities in 2020 was $768.4 million compared to $542.3 million in 2019. The increase in cash flows provided by operating activities is reflective of the increased earnings across all businesses. The increase in cash flows provided by operating activities was largely driven by stronger collection of accounts receivable at the construction services business and decreased receivables at the construction materials and contracting business as compared to the prior period
as a result of lower contracting revenues. Also contributing to the increase in cash flows provided by operating activities was the decrease in natural gas purchases in 2020 as a result of milder temperatures and lower gas costs and recovery of purchased gas cost adjustment balances at the natural gas distribution business. The Company also benefited from the deferral of payroll taxes related to the CARES Act and the absence of pension contributions at all of its businesses. Partially offsetting these increases was higher cash needs due to decreased bonus depreciation for tax purposes taken on qualified property in 2020 as compared to 2019 and a decrease in deferred taxes as a result of the purchased gas cost adjustment recorded in 2019.
Cash flows provided by operating activities in 2019 were $542.3 million compared to $499.9 million in 2018.
The increase in cash flows provided by operating activities was largely driven by increased earnings from higher workloads at the construction businesses, which were partially offset by an increase in accounts receivable as a result of the higher workloads. Lower inventory balances due to higher workloads at the construction materials and contracting business in 2019 as compared to the increase in inventory balances in 2018 due to the activity of acquired businesses also contributed to the increase. Partially offsetting these increases were higher natural gas purchases including the effects of colder weather, higher gas costs and timing of collection of such balances from customers at the natural gas distribution business, as well as higher pension contributions at all of the businesses.
Investing activities Cash flows used in investing activities in 2020 were $630.2 million compared to $603.9 million
in 2019. The increase in cash used was primarily related to additional cash needs for acquisition activity in 2020 compared to 2019 at the construction businesses, increased capital expenditures in 2020 at the electric business and lower proceeds on asset sales in 2020 at the construction materials and contracting business. Partially offsetting these increases were decreased capital expenditures in 2020 at the construction materials and contracting business, proceeds on the natural gas gathering asset sales at the pipeline business and higher proceeds on asset sales in 2020 at the construction services businesses.
Cash flows used in investing activities in 2019 was $603.9 million compared to $710.9 million in 2018. The decrease in cash used was primarily related to $112.1 million lower cash used in acquisition activity in 2019 compared to 2018 at the construction materials and contracting business and higher proceeds on asset
sales at the construction businesses in 2019.
Financing activitiesCash flows used in financing activities in 2020 was $145.1 million compared to cash flows provided by financing activities of $74.1 million in 2019. The change was largely the result of a decrease in net long-term and short-term debt borrowings in 2020 as compared to
46 MDU Resources Group, Inc. Form 10-K
Part II
2019
due to lower working capital needs. In addition, the Company had decreased net proceeds of $103.5 million in 2020 due to the absence of common stock issuance under its "at-the-market" offering and 401(k) plan.
Cash flows provided by financing activities in 2019 were $74.1 million compared to $230.4 million in 2018. The decrease in cash provided by financing activities was largely due to the higher repayment of long-term debt in 2019 on debt issued in 2018 for acquisitions at the construction materials and contracting business. The Company also borrowed and repaid short-term borrowings in 2019. Partially offsetting the decrease in cash provided by financing activities was the receipt of proceeds from the issuance of common stock. The
Company issued common stock for net proceeds of $106.8 million under its "at-the-market" offering and 401(k) plan in 2019.
Defined benefit pension plans
The Company has noncontributory qualified defined benefit pension plans for certain employees. Plan assets consist of investments in equity and fixed-income securities. Various actuarial assumptions are used in calculating the benefit expense (income) and liability (asset) related to the pension plans. Actuarial assumptions include assumptions about the discount rate and expected return on plan assets. At December 31, 2020, the pension plans' accumulated benefit obligations exceeded
these plans' assets by approximately $53.5 million. Pretax pension income reflected in the Consolidated Statements of Income for the year ended December 31, 2020, was $684,000. Pretax pension expense reflected in the Consolidated Statements of Income for the years ended December 31, 2019 and 2018, was $2.5 million and $843,000, respectively. The Company's pension income is currently projected to be approximately $1.7 million in 2021. Funding for the pension plans is actuarially determined. The Company has no minimum funding requirements for its defined benefit pension plans for 2021 due to an additional contribution of $20.0 million in 2019. There were no minimum
required contributions for the year ended December 31, 2020, and the minimum required contributions for the years ended December 31, 2019 and 2018, were approximately $4.9 million and $6.1 million, respectively. For more information on the Company's pension plans, see Item 8 - Note 18.
Capital expenditures
The Company's capital expenditures for 2018 through 2020 and as anticipated for 2021 through 2023 are summarized in the following table.
Actual*
Estimated
2018
2019
2020
2021
2022
2023
(In
millions)
Capital expenditures:
Electric
$
186
$
99
$
115
$
141
$
182
$
109
Natural
gas distribution
206
207
193
215
225
188
Pipeline
70
71
62
230
74
110
Construction
materials and contracting
280
190
191
189
154
150
Construction services
25
61
84
46
34
35
Other
2
8
3
5
4
3
Total
capital expenditures
$
769
$
636
$
648
$
826
$
673
$
595
* Capital expenditures for 2020, 2019 and 2018 include noncash transactions such as the issuance of the
Company's equity securities in connection with acquisitions, capital expenditure-related accounts payable, AFUDC and accrual of holdback payments in connection with acquisitions totaling $(15.7) million, $4.8 million and $33.4 million, respectively.
The 2020 capital expenditures include the completed business combinations at the construction materials and contracting and construction services segments, as discussed in Item 8 - Note 4. The 2020 capital expenditures were funded by internal sources and borrowings under credit facilities and issuance of commercial paper of the Company's subsidiaries.
The Company has included in the estimated capital expenditures for 2021 through 2023 the North Bakken Expansion project and construction of Heskett Unit 4, as previously discussed in Business Segment Financial and Operating Data.
Estimated capital expenditures for the years 2021 through 2023 include those for:
•System upgrades
•Routine replacements
•Service extensions
•Routine equipment maintenance and replacements
•Buildings, land and building improvements
•Pipeline
and natural gas storage projects
•Power generation and transmission opportunities
•Environmental upgrades
•Other growth opportunities
MDU Resources Group, Inc. Form 10-K 47
Part II
The
Company continues to evaluate potential future acquisitions and other growth opportunities that would be incremental to the outlined capital program; however, they are dependent upon the availability of economic opportunities and, as a result, capital expenditures may vary significantly from the estimates in the preceding table. It is anticipated that all of the funds required for capital expenditures for the years 2021 through 2023 will be funded by various sources, including internally generated funds; credit facilities and commercial paper of the Company's subsidiaries, as described later; and issuance of debt and equity securities if necessary.
Capital
resources
Certain debt instruments of the Company's subsidiaries, including those discussed later, contain restrictive and financial covenants and cross-default provisions. In order to borrow under the debt agreements, the subsidiary companies must be in compliance with the applicable covenants and certain other conditions, all of which the subsidiaries, as applicable, were in compliance with at December 31, 2020. In the event the subsidiaries do not comply with the applicable covenants and other conditions, alternative sources of funding
may need to be pursued. For more information on the covenants, certain other conditions and cross-default provisions, see Item 8 - Note 9.
(a) The commercial paper program is supported by a revolving credit agreement with various banks (provisions allow for increased borrowings, at the option of Montana-Dakota on stated conditions, up to a maximum of $225.0 million). There were no amounts outstanding under the revolving credit agreement.
(b) Certain
provisions allow for increased borrowings, up to a maximum of $125.0 million.
(c) Outstanding letter(s) of credit reduce the amount available under the credit agreement.
(d) Certain provisions allow for increased borrowings, up to a maximum of $110.0 million.
(e) The commercial paper program is supported by a revolving credit agreement with various banks (provisions allow for increased borrowings, at the option of Centennial on stated conditions, up to a maximum of $700.0 million). There were no amounts outstanding under the revolving credit agreement.
The respective commercial paper programs are supported by revolving credit
agreements. While the amount of commercial paper outstanding does not reduce available capacity under the respective revolving credit agreements, Montana-Dakota and Centennial do not issue commercial paper in an aggregate amount exceeding the available capacity under their credit agreements. The commercial paper borrowings may vary during the period, largely the result of fluctuations in working capital requirements due to the seasonality of certain operations of the Company's subsidiaries.
Total equity as a percent of total capitalization was 58 percent and 56 percent at December 31, 2020 and 2019, respectively. This ratio is calculated as the
Company's total equity, divided by the Company's total capital. Total capital is the Company's total debt, including short-term borrowings and long-term debt due within 12 months, plus total equity. This ratio is an indicator of how the Company is financing its operations, as well as its financial strength. As of December 31, 2020, the Company had investment grade credit ratings at all entities issuing debt.
The Company currently has a shelf registration statement
on file with the SEC, under which the Company may issue and sell any combination of common stock and debt securities. The Company may sell such securities if warranted by market conditions and the Company's capital requirements. Any public offer and sale of such securities will be made only by means of a prospectus meeting the requirements of the Securities Act and the rules and regulations thereunder.
In August 2020, the Company amended the Distribution Agreement dated February 22, 2019, with J.P. Morgan Securities LLC and MUFG Securities Americas Inc.,
as sales agents. The Distribution Agreement allows the offering, issuance and sale of up to 6.4 million shares of the Company's common stock in connection with an “at-the-market” offering. The common stock may be offered for sale, from time to time, in accordance with the terms and conditions of the agreement. Proceeds from the sale of shares of common stock under the agreement have been and are expected to be used for general corporate purposes, which may include, among other things, working capital, capital expenditures, debt repayment and the financing of acquisitions.
The Company did not issue any shares of common stock for the year ended December 31, 2020, pursuant to the “at-the-market” offering.
As of December 31, 2020, the Company had capacity to issue up to 6.4 million additional shares of common stock under the "at-the-market" offering program. For more information on the Company's "at-the-market" offering, see Item 8 - Note 12.
Certain of the Company's debt instruments use LIBOR as a benchmark for establishing the applicable interest rate. LIBOR is the subject of recent national, international and other regulatory guidance and proposals for reform. These reforms and other pressures may cause LIBOR to disappear entirely or to perform differently than in the past. The
Company has been proactive to anticipate the reform of LIBOR by replacing it with SOFR in certain of its new debt instruments, as well as those that are being renewed. The Company continues to evaluate the impact the reform will have on its debt instruments and, at this time, does not anticipate a significant impact.
48 MDU Resources Group, Inc. Form 10-K
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The
following includes information related to the preceding table.
Montana-Dakota On January 1, 2019, the Company's revolving credit agreement and commercial paper program became Montana-Dakota's revolving credit agreement and commercial paper program as a result of the Holding Company Reorganization. The outstanding balance of the revolving credit agreement was also transferred to Montana-Dakota. All of the related terms and covenants of the credit agreements remained the same.
On December 19, 2019, Montana-Dakota amended and restated its revolving credit agreement extending the maturity date to December 19, 2024. Montana-Dakota's revolving
credit agreement supports its commercial paper program. Commercial paper borrowings under this agreement are classified as long-term debt as they are intended to be refinanced on a long-term basis through continued commercial paper borrowings. Montana-Dakota's objective is to maintain acceptable credit ratings in order to access the capital markets through the issuance of commercial paper. Historically, downgrades in credit ratings have not limited, nor are currently expected to limit, Montana-Dakota's ability to access the capital markets. If Montana-Dakota were to experience a downgrade of its credit ratings in the future, it may need to borrow under its credit agreement and may experience an increase in overall interest rates with respect to its cost of borrowings. Prior to the maturity of the credit agreement, Montana-Dakota expects that it will negotiate the extension or replacement of this agreement. If Montana-Dakota is unable to successfully negotiate an extension
of, or replacement for, the credit agreement, or if the fees on this facility become too expensive, which Montana-Dakota does not currently anticipate, it would seek alternative funding.
On April 8, 2020, Montana-Dakota entered into a $75.0 million term loan agreement with a LIBOR-based variable interest rate and a maturity date of April 7, 2021. At December 31, 2020, Montana-Dakota had $50.0 million outstanding under this agreement. On February 16, 2021, Montana-Dakota repaid the remaining $50.0 million outstanding.
Cascade On June 7, 2019, Cascade amended its revolving credit agreement to increase the borrowing
limit to $100.0 million and extend the maturity date to June 7, 2024. Any borrowings under the revolving credit agreement are classified as long-term debt as they are intended to be refinanced on a long-term basis through continued borrowings.
On June 15, 2020, Cascade issued $50.0 million of senior notes under a note purchase agreement with maturity dates ranging from June 15, 2050 to June 15, 2060, at a weighted average interest rate of 3.66 percent.
On October 30, 2020, Cascade issued $25.0 million of senior notes under a note purchase agreement with a maturity date of October 30, 2060, at an interest rate of 3.34 percent.
Intermountain On June 7,
2019, Intermountain amended its revolving credit agreement to extend the maturity date to June 7, 2024. Any borrowings under the revolving credit agreement are classified as long-term debt as they are intended to be refinanced on a long-term basis through continued borrowings.
Centennial On December 19, 2019, Centennial amended and restated its revolving credit agreement to increase the borrowing capacity to $600.0 million and extend the maturity date to December 19, 2024. Centennial's revolving credit agreement supports its commercial paper program. Commercial paper borrowings under this agreement are classified as long-term debt as they are intended to be refinanced on a long-term basis through continued commercial paper borrowings. Centennial's objective
is to maintain acceptable credit ratings in order to access the capital markets through the issuance of commercial paper. Historically, downgrades in Centennial's credit ratings have not limited, nor are currently expected to limit, Centennial's ability to access the capital markets. If Centennial were to experience a downgrade of its credit ratings in the future, it may need to borrow under its credit agreement and may experience an increase in overall interest rates with respect to its cost of borrowings. Prior to the maturity of the Centennial credit agreement, Centennial expects that it will negotiate the extension or replacement of this agreement, which provides credit support to access the capital markets. In the event Centennial is unable to successfully negotiate this agreement, or in the event the fees on this facility become too expensive, which Centennial does not currently anticipate, it would seek alternative funding.
WBI
Energy Transmission On July 26, 2019, WBI Energy Transmission amended its uncommitted note purchase and private shelf agreement to increase capacity to $300.0 million and extend the issuance period and expiration date to May 16, 2022. On December 16, 2020, WBI Energy Transmission issued $25.0 million of senior notes under the private shelf agreement with a maturity date of December 16, 2035, at an interest rate of 3.26 percent. WBI Energy Transmission had $195.0 million of notes outstanding at December 31, 2020, which reduced the remaining capacity under this uncommitted private shelf agreement to $105.0 million.
Dividend
restrictions
For information on the Company's dividends and dividend restrictions, see Item 8 - Note 12.
Off balance sheet arrangements
As of December 31, 2020, the Company had no material off balance sheet arrangements as defined by the rules of the SEC.
MDU Resources Group, Inc.
Form 10-K 49
Part II
Contractual obligations and commercial commitments
For more information on the Company's contractual obligations on long-term debt, operating leases and purchase commitments, see
Item 8 - Notes 9, 10 and 21. At December 31, 2020, the
Company's commitments under these obligations were as follows:
Less than 1 year
1-3 years
3-5 years
More than 5 years
Total
(In millions)
Long-term
debt maturities*
$
1.6
$
225.9
$
460.7
$
1,530.7
$
2,218.9
Estimated interest payments**
90.8
173.5
156.4
770.3
1,191.0
Operating
leases
36.6
41.8
20.0
48.8
147.2
Purchase commitments
458.4
409.2
223.6
691.6
1,782.8
$
587.4
$
850.4
$
860.7
$
3,041.4
$
5,339.9
* Unamortized
debt issuance costs and discount are excluded from the table.
** Represents the estimated interest payments associated with the Company's long-term debt outstanding at December 31, 2020, assuming current interest rates and consistent amounts outstanding until their respective maturity dates over the periods indicated in the table above.
At December 31, 2020, the Company had total liabilities of $446.9 million related to asset retirement obligations that
are excluded from the table above. Of the total asset retirement obligations, the current portion was $6.6 million at December 31, 2020, and was included in other accrued liabilities on the Consolidated Balance Sheets. Due to the nature of these obligations, the Company cannot determine precisely when the payments will be made to settle these obligations. For more information, see Item 8 - Note 11.
Not reflected in the previous table are $1.3 million in uncertain tax positions at December 31, 2020.
The Company has no minimum funding requirements for its defined benefit pension plans for 2021 due to an additional contribution
of $20.0 million in 2019.
The Company's MEPP contributions are based on union employee payroll, which cannot be determined in advance for future periods. The Company may also be required to make additional contributions to its MEPPs as a result of their funded status. For more information, see Item 1A - Risk Factors and Item 8 - Note 18.
The Company has prepared its financial statements in conformity with GAAP. The preparation of its financial statements requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities, and disclosure of contingent assets and liabilities, at the date of the financial statements, as well as the reported amounts of revenues and expenses during the reporting period. Management reviews these estimates and assumptions based on historical experience, changes in business conditions and other relevant factors believed to be reasonable under the circumstances.
Critical accounting estimates are defined as estimates that require management to make assumptions about matters that are uncertain at the time the estimate was made and changes in the estimates could
have a material impact on the Company's financial position or results of operations. The Company's critical accounting estimates are subject to judgments and uncertainties that affect the application of its significant accounting policies discussed in Item 8 - Note 2. As additional information becomes available, or actual amounts are determinable, the recorded estimates are revised. Consequently, the Company's financial position or results of operations may be materially different when reported under different conditions or when using different assumptions in the application of the following critical accounting estimates.
Goodwill
The
Company performs its goodwill impairment testing annually in the fourth quarter. In addition, the test is performed on an interim basis whenever events or circumstances indicate that the carrying amount of goodwill may not be recoverable. Examples of such events or circumstances may include a significant adverse change in business climate, weakness in an industry in which the Company's reporting units operate or recent significant cash or operating losses with expectations that those losses will continue.
The Company has determined that the reporting units for its goodwill impairment test are its operating segments, or components of an operating segment, that constitute a business for which discrete financial information is available and for which segment management
regularly reviews the operating results. For more information on the Company's operating segments, see Item 8 - Note 17. Goodwill impairment, if any, is measured by comparing the fair value of each reporting unit to its carrying value. If the fair value of a reporting unit exceeds its carrying value, the goodwill of the reporting unit is not impaired. If the carrying value of a reporting unit exceeds its fair value, the Company must record an impairment loss for the
50 MDU Resources Group, Inc. Form 10-K
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amount that the carrying value of the reporting unit, including goodwill, exceeds the fair value of the reporting unit. For the years ended December 31, 2020, 2019 and 2018, there were no impairment losses recorded. At October 31, 2020, the fair value substantially exceeded the carrying value at all reporting units.
Determining the fair value of a reporting unit requires judgment and the use of significant estimates which include assumptions about the
Company's future revenue, profitability and cash flows, amount and timing of estimated capital expenditures, inflation rates, risk adjusted capital cost, operational plans, and current and future economic conditions, among others. The fair value of each reporting unit is determined using a weighted combination of income and market approaches. The Company uses a discounted cash flow methodology for its income approach. Under the income approach, the discounted cash flow model determines fair value based on the present value of projected cash flows over a specified period and a residual value related to future cash flows beyond the projection period. Both values are discounted using a rate which reflects the best estimate of the risk adjusted capital cost at each reporting unit. Risk adjusted capital cost, which varies by reporting unit and was in the range of 4 percent to 8 percent,
was utilized in the goodwill impairment test performed in the fourth quarter of 2020. The goodwill impairment test also utilized a long-term growth rate projection, which varies by reporting unit and was in the range of approximately 1 percent to 3 percent, in the goodwill impairment test performed in the fourth quarter of 2020. Under the market approach, the Company estimates fair value using various multiples derived from enterprise value to EBITDA for comparative peer companies for each respective reporting unit. These multiples are applied to operating data for each reporting unit to arrive at an indication of fair value. In addition, the Company adds a reasonable control premium when calculating the fair value utilizing the peer multiples, which is estimated as the premium that would be received in
a sale in an orderly transaction between market participants. The Company believes that the estimates and assumptions used in its impairment assessments are reasonable and based on available market information.
Business combinations
The Company accounts for acquisitions on the Consolidated Financial Statements starting from the date of the acquisition, which is the date that control is obtained. The acquisition method of accounting requires acquired assets and liabilities assumed be recorded at their respective fair values as of the date of the acquisition. The excess of the purchase price over the fair value of the assets acquired and liabilities assumed is recorded as goodwill. The estimation of fair values of acquired assets
and liabilities assumed by the Company requires significant judgment and requires various assumptions. Although independent appraisals may be used to assist in the determination of the fair value of certain assets and liabilities, the appraised values may be based on significant estimates provided by management. The amounts and useful lives assigned to depreciable and amortizable assets compared to amounts assigned to goodwill, which is not amortized, can affect the results of operations in the period of and periods subsequent to a business combination.
In determining fair values of acquired assets and liabilities assumed, the Company uses various observable inputs for similar assets or liabilities in active markets and various unobservable inputs, which includes
the use of valuation models. Fair values are based on various factors including, but not limited to, age and condition of property, maintenance records, auction values for equipment with similar characteristics, recent sales and listings of comparable properties, data collected from drill holes and other subsurface investigations and geologic data. The Company primarily uses the market and cost approaches in determining the fair value of land and property, plant and equipment. A combination of the market and income approaches are used for aggregate reserves and intangibles, primarily a discounted cash flow model.
There is a measurement period after the acquisition date during which the Company may adjust the amounts recognized for a business combination. Any such
adjustments are recorded in the period the adjustment is determined with the corresponding offset to goodwill. These adjustments are typically based on obtaining additional information that existed at the acquisition date regarding the assets acquired and the liabilities assumed. The measurement period ends once the Company has obtained all necessary information that existed as of the acquisition date, but does not extend beyond one year from the date of the acquisition. Once the measurement period has ended, any adjustments to assets acquired or liabilities assumed are recorded in income from continuing operations.
Regulatory accounting
The Company is subject to rate regulation by state public service commissions and/or the FERC.
The Company's regulated businesses account for certain income and expense items under the provisions of regulatory accounting, which require these businesses to defer as regulatory assets or liabilities certain items that would have otherwise been reflected as expense or income, respectively, based on the expected regulatory treatment in future rates. Regulatory assets generally represent incurred or accrued costs that have been deferred and are expected to be recovered in rates charged to customers. Regulatory liabilities generally represent amounts that are expected to be refunded to customers in future rates or amounts collected in current rates for future costs.
Management continually assesses the likelihood of recovery in future rates of incurred costs and refunds to customers associated with regulatory assets and liabilities. Decisions
made by the various regulatory agencies can directly impact the amount and timing of these items. Therefore, expected recovery or flowback of these deferred items generally is based on specific ratemaking decisions or precedent for each item. If future recovery of costs is no longer probable, the Company would be required to include those costs in the statement of income or accumulated other comprehensive income (loss) in the period in which it is no longer deemed probable. The Company believes that the accounting subject to rate regulation remains appropriate and its regulatory assets are probable of recovery in current rates or in future rate proceedings. At December 31, 2020 and 2019, the
Company's regulatory assets were $447.9 million and $417.4 million, respectively, and regulatory liabilities were $459.5 million and $490.3 million, respectively.
MDU Resources Group, Inc. Form 10-K 51
Part II
Revenue recognition
Revenue is recognized to depict the transfer of promised goods or services to customers
in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. The recognition of revenue requires the Company to make estimates and assumptions that affect the reported amounts of revenue. The accuracy of revenues reported on the Consolidated Financial Statements depends on, among other things, management's estimates of total costs to complete projects because the Company uses the cost-to-cost measure of progress on construction contracts for revenue recognition.
To determine the proper revenue recognition method for contracts,
the Company evaluates whether two or more contracts should be combined and accounted for as one single contract and whether the combined or single contract should be accounted for as more than one performance obligation. This evaluation requires significant judgment and the decision to combine a group of contracts or separate the combined or single contract into multiple performance obligations could change the amount of revenue and profit recorded
in a given period. For most contracts, the customer contracts with the Company to provide a significant service of integrating a complex set of tasks and components into a single project. Hence, the Company's contracts are generally accounted for as one performance obligation.
The Company recognizes construction contract revenue
over time using an input method based on the cost-to-cost measure of progress for contracts because it best depicts the transfer of assets to the customer which occurs as the Company incurs costs on the contract. Under the cost-to-cost measure of progress, the costs incurred are compared with total estimated costs of a performance obligation. Revenues are recorded proportionately to the costs incurred. This method depends largely on the ability to make reasonably dependable estimates related to the extent of progress toward completion of the contract, contract
revenues and contract costs. Inasmuch as contract prices are generally set before the work is performed, the estimates pertaining to every project could contain significant unknown risks such as volatile labor, material and fuel costs, weather delays, adverse project site conditions, unforeseen actions by regulatory agencies, performance by subcontractors, job management and relations with project owners. Changes in estimates could have a material effect on the Company's results of operations, financial position and cash flows. For the years ended December 31, 2020 and 2019, the
Company's total construction contract revenue was $3.1 billion and $2.8 billion, respectively.
Several factors are evaluated in determining the bid price for contract work. These include, but are not limited to, the complexities of the job, past history performing similar types of work, seasonal weather patterns, competition and market conditions, job site conditions, work force safety, reputation of the project owner, availability of labor, materials and fuel, project location and project completion dates. As a project commences, estimates are continually monitored and revised as information becomes available and actual costs and conditions surrounding the job become known. If a loss is anticipated on a contract,
the loss is immediately recognized.
Contracts are often modified to account for changes in contract specifications and requirements. The Company considers contract modifications to exist when the modification either creates new or changes the existing enforceable rights and obligations. Generally, contract modifications are for goods or services that are not distinct from the existing contract due to the
significant integration of services provided in the context of the contract and are accounted for as if they were part of that existing contract. The effect of a contract modification on the transaction price and the measure of progress for the performance obligation to which it relates, is recognized as an adjustment to revenue on a cumulative catch-up basis.
The Company's construction contracts generally contain variable consideration including liquidated damages, performance bonuses or incentives,
claims, unapproved/unpriced change orders and penalties or index pricing. The variable amounts usually arise upon achievement of certain performance metrics or change in project scope. The Company estimates the amount of revenue to be recognized on variable consideration using estimation methods that best predict the most likely amount of consideration the Company expects to be entitled to or expects to incur. The Company includes variable consideration in the estimated transaction price to the extent it is probable that a significant reversal of cumulative revenue recognized will not occur or when the uncertainty associated with the variable consideration is resolved. Changes in circumstances could impact management's estimates
made in determining the value of variable consideration recorded. The Company updates its estimate of the transaction price each reporting period and the effect of variable consideration on the transaction price is recognized as an adjustment to revenue on a cumulative catch-up basis.
The Company believes its estimates surrounding the cost-to-cost method are reasonable based on the information that is known when the estimates are made. The Company has contract administration, accounting and management control systems in place that allow its estimates to be updated and monitored on a regular basis.
Because of the many factors that are evaluated in determining bid prices, it is inherent that the Company's estimates have changed in the past and will continually change in the future as new information becomes available for each job.
Pension and other postretirement benefits
The Company has noncontributory defined benefit pension plans and other postretirement benefit plans for certain eligible employees. Various actuarial assumptions are used in calculating the benefit expense (income) and liability (asset) related to these plans. Costs of providing pension and other postretirement benefits bear the risk of change, as they are dependent upon numerous factors based on assumptions of future conditions.
The
Company makes various assumptions when determining plan costs, including the current discount rates and the expected long-term return on plan assets, the rate of compensation increases, actuarially determined mortality data and health care cost trend rates. In selecting the expected long-term return on plan assets, which is considered to be one of the key variables in determining benefit expense or income, the Company considers historical returns, current market conditions, the mix of investments and expected future market trends, including changes in interest rates and
52 MDU Resources Group, Inc. Form 10-K
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equity and bond market performance. Another key variable in determining benefit expense or income is the discount rate. In selecting the discount rate, the Company matches forecasted future cash flows of the pension and postretirement plans to a yield curve which consists of a hypothetical portfolio of high-quality corporate bonds with varying maturity dates, as well as other factors, as a basis. The Company's pension and other postretirement benefit plan assets are primarily made up of equity and fixed-income investments. Fluctuations in actual equity and bond market returns, as well as changes
in general interest rates, may result in increased or decreased pension and other postretirement benefit costs in the future. Management estimates the rate of compensation increase based on long-term assumed wage increases and the health care cost trend rates are determined by historical and future trends. The Company estimates that a 50-basis point decrease in the discount rate or in the expected return on plan assets would each increase expense by approximately $2.0 million (after-tax) for the year ended December 31, 2020.
The Company believes the estimates made for its pension and other postretirement benefits are reasonable based on the information that is known when the estimates are made. These estimates and
assumptions are subject to a number of variables and are expected to change in the future. Estimates and assumptions will be affected by changes in the discount rate, the expected long-term return on plan assets, the rate of compensation increase and health care cost trend rates. The Company plans to continue to use its current methodologies to determine plan costs. For more information on the assumptions used in determining plan costs, see Item 8 - Note 18.
Income taxes
The Company is required to make judgments regarding the potential tax effects of various financial transactions and ongoing operations to estimate the Company's obligation to taxing
authorities. These tax obligations include income, real estate, franchise and sales/use taxes. Judgments related to income taxes require the recognition in the Company's financial statements that a tax position is more-likely-than-not to be sustained on audit.
Judgment and estimation is required in developing the provision for income taxes and the reporting of tax-related assets and liabilities and, if necessary, any valuation allowances. The interpretation of tax laws can involve uncertainty, since tax authorities may interpret such laws differently. Actual income tax could vary from estimated amounts and may result in favorable or unfavorable impacts to net income, cash flows and tax-related assets and liabilities. In addition, the effective tax rate may be affected by other changes including the allocation of property, payroll and revenues
between states.
The Company assesses the deferred tax assets for recoverability taking into consideration historical and anticipated earnings levels; the reversal of other existing temporary differences; available net operating losses and tax carryforwards; and available tax planning strategies that could be implemented to realize the deferred tax assets. Based on this assessment, management must evaluate the need for, and amount of, a valuation allowance against the deferred tax assets. As facts and circumstances change, adjustment to the valuation allowance may be required.
Non-GAAP Financial Measures
The Business Segment Financial and Operating Data
includes financial information prepared in accordance with GAAP, as well as another financial measure, adjusted gross margin, that is considered a non-GAAP financial measure as it relates to the Company's electric and natural gas distribution segments. The presentation of adjusted gross margin is intended to be a useful supplemental financial measure for investors’ understanding of the segments' operating performance. This non-GAAP financial measure should not be considered as an alternative to, or more meaningful than, GAAP financial measures such as operating income (loss) or net income (loss). The Company's non-GAAP financial measure, adjusted gross margin, is not standardized; therefore, it may not be possible to compare this financial measure with other companies’ gross margin measures having the same
or similar names.
In addition to operating revenues and operating expenses, management also uses the non-GAAP financial measure of adjusted gross margin when evaluating the results of operations for the electric and natural gas distribution segments. Adjusted gross margin for the electric and natural gas distribution segments is calculated by adding back adjustments to operating income (loss). These add-back adjustments include: operation and maintenance expense; depreciation, depletion and amortization expense; and certain taxes, other than income.
Adjusted gross margin includes operating revenues less the cost of electric fuel and purchased power, purchased natural gas sold and certain taxes, other than income. These taxes, other than income, included as a reduction to adjusted gross margin relate to revenue taxes. These segments pass on to their customers the increases and decreases
in the wholesale cost of power purchases, natural gas and other fuel supply costs in accordance with regulatory requirements. As such, the segments' revenues are directly impacted by the fluctuations in such commodities. Revenue taxes, which are passed back to customers, fluctuate with revenues as they are calculated as a percentage of revenues. For these reasons, period over period, the segments' operating income (loss) is generally not impacted. The Company's management believes the adjusted gross margin is a useful supplemental financial measure as these items are included in both operating revenues and operating expenses. The Company's management also believes that adjusted gross margin and the remaining operating expenses that calculate operating income (loss) are useful to investors in assessing the
Company's utility performance as management has the ability to influence control over the remaining operating expenses.
MDU Resources Group, Inc. Form 10-K 53
Part II
The following information reconciles operating income to adjusted gross margin for the electric segment.
Inflation did not have a significant effect on the
Company's operations in 2020, 2019 or 2018.
Item 7A. Quantitative and Qualitative Disclosures About Market Risk
The Company is exposed to the impact of market fluctuations associated with commodity prices and interest rates. The Company has policies and procedures to assist in controlling these market risks and from time to time has utilized derivatives to manage a portion of its risk.
Interest rate risk
The Company uses fixed and variable
rate long-term debt to partially finance capital expenditures, including acquisitions, and mandatory debt retirements. These debt agreements expose the Company to market risk related to changes in interest rates. The Company manages this risk by taking advantage of market conditions when timing the placement of long-term financing. The Company from time to time has utilized interest rate swap agreements to manage a portion of the Company's interest rate risk and may take advantage of such agreements in the future to minimize such risk. For additional information on the
Company's long-term debt, see Item 8 - Notes 8 and 9. At December 31, 2020 and 2019, the Company had no outstanding interest rate hedges.
The following table shows the amount of long-term debt, which excludes unamortized debt issuance costs and discount, and related weighted average interest rates, both by expected maturity dates, as of December 31, 2020.
2021
2022
2023
2024
2025
Thereafter
Total
Fair Value
(Dollars
in millions)
Long-term debt:
Fixed rate
$
1.6
$
148.0
$
77.9
$
61.4
$
177.8
$
1,530.7
$
1,997.4
$
2,321.6
Weighted
average interest rate
1.1
%
4.5
%
3.7
%
4.2
%
4.0
%
4.5
%
4.4
%
Variable rate
$
—
$
—
$
—
$
221.5
$
—
$
—
$
221.5
$
221.5
Weighted
average interest rate
—
%
—
%
—
%
1.0
%
—
%
—
%
1.0
%
Commodity price risk
The Company enters into commodity
price derivative contracts to minimize the price volatility associated with natural gas costs at its natural gas distribution segment. At December 31, 2020 and 2019, these contracts were not material. For more information on the Company's derivatives, see Item 8 - Note 2.
54 MDU Resources Group, Inc. Form 10-K
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Item 8. Financial Statements and Supplementary Data
Management's Report on Internal Control Over Financial Reporting
The management of MDU Resources Group, Inc. is responsible for establishing and maintaining adequate internal control over financial reporting as defined in Rules 13a-15(f) and 15d-15(f) under the Securities Exchange Act of 1934. The Company's internal control system is designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of the Company's
financial statements for external purposes in accordance with generally accepted accounting principles in the United States of America.
All internal control systems, no matter how well designed, have inherent limitations. Therefore, even those systems determined to be effective can provide only reasonable assurance with respect to financial statement preparation and presentation. Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.
Management assessed the effectiveness of the Company's internal
control over financial reporting as of December 31, 2020. In making this assessment, management used the criteria set forth by the Committee of Sponsoring Organizations of the Treadway Commission (COSO) in Internal Control-Integrated Framework (2013).
Based on our evaluation under the framework in Internal Control-Integrated Framework (2013), management concluded that the Company's internal control over financial reporting was effective as of December 31, 2020.
The effectiveness of the Company's internal control over financial reporting
as of December 31, 2020, has been audited by Deloitte & Touche LLP, an independent registered public accounting firm, as stated in their report.
Report of Independent Registered Public Accounting Firm
To the Stockholders and the Board of Directors of MDU Resources Group, Inc.
Opinion on the Financial Statements
We have audited the accompanying consolidated balance sheets of MDU Resources Group, Inc. and subsidiaries (the "Company") as of December 31, 2020 and 2019, the related consolidated statements of income, comprehensive income, equity, and cash flows for each of the three years
in the period ended December 31, 2020, and the related notes and the financial statement schedules listed in the Index at Item 15 (collectively referred to as the "financial statements"). In our opinion, the financial statements present fairly, in all material respects, the financial position of the Company as of December 31, 2020 and 2019, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 2020, in conformity with accounting principles generally accepted in the United States of America.
We have also audited, in accordance with the standards of the Public Company Accounting Oversight
Board (United States) (PCAOB), the Company's internal control over financial reporting as of December 31, 2020, based on criteria established in Internal Control-Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission and our report dated February 19, 2021, expressed an unqualified opinion on the Company's internal control over financial reporting.
Basis for Opinion
These financial statements are the responsibility of the Company's management.
Our responsibility is to express an opinion on the Company's financial statements based on our audits. 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 audits in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement, whether due to error or fraud. Our audits included performing procedures to assess the risks of material misstatement of the financial statements, whether due to error
or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the financial statements. We believe that our audits provide a reasonable basis for our opinion.
Critical Audit Matters
The critical audit matters communicated below are matters arising from the current-period audit of the financial statements that were communicated or required to be communicated to the audit committee and that (1) relate to accounts or disclosures that are material to the financial statements and (2) involved our especially challenging, subjective, or complex judgments. The communication of critical audit matters
does not alter in any way our opinion on the financial statements, taken as a whole, and we are not, by communicating the critical audit matters below, providing separate opinions on the critical audit matters or on the accounts or disclosures to which they relate.
Revenue from Contracts with Customers-Construction Contract Revenue-Refer to Notes 2 and 3 to the financial statements
Critical Audit Matter Description
The Company recognizes construction contract revenue over time using an input method based
on the cost-to-cost measure of progress as it best depicts the transfer of assets to the customer. Under this method of measuring progress, costs incurred are compared with total estimated costs of the performance obligation and revenues are recorded proportionately to the costs incurred. Ordinarily the Company’s contracts represent a single distinct performance obligation due to the highly interdependent and interrelated nature of the underlying goods or services. For the year ended December 31, 2020, the Company recognized $3.1 billion of construction contract revenue.
Given
the judgments necessary to estimate total costs and profit for the performance obligations used to recognize revenue for construction contracts, auditing such estimates required extensive audit effort due to the volume and complexity of construction contracts and a high degree of auditor judgment when performing audit procedures and evaluating the results of those procedures.
How the Critical Audit Matter Was Addressed in the Audit
Our audit procedures related to management’s estimates of total costs and profit for the performance obligations used to recognize revenue for certain construction contracts included the
following, among others:
•We tested the design and operating effectiveness of management's controls over construction contract revenue, including those over management’s estimation of total costs and profit for the performance obligations.
56 MDU Resources Group, Inc. Form 10-K
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•We
developed an expectation of the amount of construction contract revenues for certain performance obligations based on prior year markups, and taking into account current year events, applied to the construction contract costs in the current year and compared our expectation to the amount of construction contract revenues recorded by management.
•We selected a sample of construction contracts and performed the following:
•Evaluated whether the contracts
were properly included in management’s calculation of construction contract revenue based on the terms and conditions of each contract, including whether continuous transfer of control to the customer occurred as progress was made toward fulfilling the performance obligation.
•Compared the transaction prices to the consideration expected to be received based on current rights and obligations under the contracts and any modifications that were agreed upon with the customers.
•Evaluated management’s identification of distinct performance obligations by evaluating whether
the underlying goods, services, or both were highly interdependent and interrelated.
•Tested the accuracy and completeness of the costs incurred to date for the performance obligation.
•Evaluated the estimates of total cost and profit for the performance obligation by:
◦Comparing total costs incurred to date to the costs management estimated to be incurred to date and selecting specific cost types to compare costs incurred to date to management's estimated costs at completion.
◦Evaluating management’s ability to achieve the estimates of total cost and profit by performing corroborating inquiries with the Company’s
project managers and engineers, and comparing the estimates to management’s work plans, engineering specifications, and supplier contracts.
◦Comparing management’s estimates for the selected contracts to costs and profits of similar performance obligations, when applicable.
•Tested the mathematical accuracy of management’s calculation of construction contract revenue for the performance obligation.
•We evaluated management’s ability to estimate total costs and profits accurately by comparing actual
costs and profits to management’s historical estimates for performance obligations that have been fulfilled.
Regulatory Matters-Impact of Rate Regulation on the Financial Statements-Refer to Notes 2 and 20 to the financial statements
Critical Audit Matter Description
Through the Company’s regulated utility businesses, it provides electric and natural gas services to customers, and generates, transmits, and distributes electricity. The Company is subject to rate regulation by federal and state utility regulatory agencies (collectively, the “Commissions”), which have jurisdiction with respect to the rates of electric and natural gas distribution companies in states where the
Company operates. The Company’s regulated utility businesses account for certain income and expense items under the provisions of regulatory accounting, which requires these businesses to defer as regulatory assets or liabilities certain items that would have otherwise been reflected as expense or income, respectively, based on the expected regulatory treatment in future rates. The expected recovery or flowback of these deferred items generally is based on specific ratemaking decisions or precedent for each item.
Rates are determined and approved in regulatory proceedings based on an analysis of the Company’s costs to provide utility service and a return on the Company’s investment
in the regulated utility businesses. Regulatory decisions can have an impact on the recovery of costs, the rate of return earned on investment, and the timing and amount of assets to be recovered by rates. The regulation of rates is premised on the full recovery of prudently incurred costs and a reasonable rate of return on invested capital. Decisions to be made by the Commissions in the future will impact the accounting for regulated operations.
Accounting for the economics of rate regulation impacts multiple financial statement line items and disclosures, such as property, plant, and equipment; regulatory assets and liabilities; operating revenues; operation and maintenance expense; and depreciation expense. We identified the impact of rate regulation as a critical audit matter due to the significant judgments made by management to support its assertions about impacted account balances and disclosures and the degree of subjectivity
involved in assessing the impact of future regulatory orders on the financial statements. Management judgments include assessing the likelihood of (1) recovery in future rates of incurred costs and (2) refunds to customers. Given management’s accounting judgments are based on assumptions about the outcome of future decisions by the Commissions, auditing these judgments requires specialized knowledge of accounting for rate regulation due to its inherent complexities.
How the Critical Audit Matter Was Addressed in the Audit
Our audit procedures related to the uncertainty of future decisions by the Commissions included the following, among others:
•We tested the design and operating effectiveness of management’s controls over the evaluation of the likelihood of (1) the recovery in future rates of costs incurred as property,
plant, and equipment and deferred as regulatory assets; and (2) a refund or a future reduction in rates that should be reported as regulatory liabilities. We tested management’s controls over the initial recognition of amounts as regulatory assets or liabilities; and the monitoring and evaluation of regulatory developments that may affect the likelihood of recovering costs in future rates or of a future reduction in rates.
•We evaluated the Company’s disclosures related to the impacts of rate regulation, including the balances recorded and regulatory developments.
MDU Resources Group, Inc.
Form 10-K 57
Part II
•We read relevant regulatory orders issued by the Commissions for the Company and other public utilities in the Company’s significant jurisdictions, regulatory statutes, interpretations, procedural memorandums, filings made by interveners, and other publicly available information to assess the likelihood of recovery in future rates or of a future reduction in rates based on precedents of the
treatment of similar costs under similar circumstances. We evaluated the external information and compared to management’s recorded regulatory asset and liability balances for completeness.
•For regulatory matters in process, we inspected the Company’s filings with the Commissions and the filings with the Commissions by intervenors that may impact the Company’s future rates, for any evidence that might contradict management’s assertions.
•We obtained an analysis from management regarding probability of recovery for regulatory assets or refund or future reduction in rates for regulatory liabilities not yet addressed in a regulatory order to assess management’s assertion that
amounts are probable of recovery, or a future reduction in rates.
We have served as the Company's auditor since 2002.
58 MDU
Resources Group, Inc. Form 10-K
Part II
Report of Independent Registered Public Accounting Firm
To the Stockholders and the Board of Directors of MDU Resources Group, Inc.
Opinion on Internal Control over Financial Reporting
We have audited the internal control over financial reporting of MDU Resources Group, Inc. and subsidiaries (the "Company")
as of December 31, 2020, based on criteria established in Internal Control-Integrated Framework(2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO). In our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of December 31, 2020, based on criteria established in Internal Control-Integrated Framework (2013) issued by COSO.
We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (PCAOB), the consolidated financial statements and financial statement
schedules as of and for the year ended December 31, 2020, of the Company and our report dated February 19, 2021, expressed an unqualified opinion on those consolidated financial statements and financial statement schedules.
Basis for Opinion
The Company's management is responsible for maintaining effective internal control over financial reporting and for its assessment of the effectiveness of internal control over financial reporting, included in the accompanying Management's Report on Internal Control Over Financial Reporting. Our responsibility is to express an opinion on the
Company's internal control over financial reporting based on our audit. 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 audit in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether effective internal control over financial reporting was maintained in all material respects. Our audit included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, testing and evaluating the design and operating effectiveness of internal control based on the assessed
risk, and performing such other procedures as we considered necessary in the circumstances. We believe that our audit provides a reasonable basis for our opinion.
Definition and Limitations of Internal Control over Financial Reporting
A company’s internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. A company’s internal control over financial reporting includes those policies and procedures that (1) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (2) provide reasonable assurance
that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (3) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company’s assets that could have a material effect on the financial statements.
Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to
future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.
Reclassification adjustment for loss on derivative instruments included in net income, net of tax of $i145, $(i140)
and $i429 in 2020, 2019 and 2018, respectively
i446
i731
i162
Postretirement
liability adjustment:
Postretirement liability gains (losses) arising during the period, net of tax of $(i2,606), $(i2,012)
and $i1,471 in 2020, 2019 and 2018, respectively
(i8,395)
(i6,151)
i4,441
Amortization
of postretirement liability losses included in net periodic benefit cost, net of tax of $i630, $i476
and $i721 in 2020, 2019 and 2018, respectively
i1,922
i1,486
i2,173
Postretirement
liability adjustment
(i6,473)
(i4,665)
i6,614
Foreign
currency translation adjustment:
Foreign currency translation adjustment recognized during the period, net of tax of $i0, $i0
and $(i14) in 2020, 2019 and 2018, respectively
i—
i—
(i61)
Reclassification
adjustment for foreign currency translation adjustment included in net income, net of tax of $i0, $i0
and $i75 in 2020, 2019 and 2018, respectively
i—
i—
i249
Foreign
currency translation adjustment
i—
i—
i188
Net
unrealized gain (loss) on available-for-sale investments:
Net unrealized gain (loss) on available-for-sale investments arising during the period, net of tax of $i0, $i35
and $(i38) in 2020, 2019 and 2018, respectively
(i1)
i134
(i144)
Reclassification
adjustment for loss on available-for-sale investments included in net income, net of tax of $i14, $i10
and $i35 in 2020, 2019 and 2018, respectively
i52
i40
i131
Net
unrealized gain (loss) on available-for-sale investments
i51
i174
(i13)
Other
comprehensive income (loss)
(i5,976)
(i3,760)
i6,951
Comprehensive
income attributable to common stockholders
$
i384,229
$
i331,693
$
i279,269
The
accompanying notes are an integral part of these consolidated financial statements.
Income
(loss) from discontinued operations, net of tax
(i322)
i287
i2,932
Income
from continuing operations
i390,527
i335,166
i269,386
Adjustments
to reconcile net income to net cash provided by operating activities:
Depreciation, depletion and amortization
i285,100
i256,017
i220,205
Deferred
income taxes
(i1,801)
i63,415
i59,735
Changes
in current assets and liabilities, net of acquisitions:
Receivables
i7,796
(i104,374)
i28,234
Inventories
(i7,221)
i9,331
(i46,796)
Other
current assets
i31,601
(i38,283)
(i31,814)
Accounts
payable
i15,955
i30,079
i21,109
Other
current liabilities
i35,591
i51,278
i22,285
Other
noncurrent changes
i12,201
(i60,813)
(i38,521)
Net
cash provided by continuing operations
i769,749
i541,816
i503,823
Net
cash provided by (used in) discontinued operations
(i1,375)
i464
(i3,942)
Net
cash provided by operating activities
i768,374
i542,280
i499,881
Investing
activities:
Capital expenditures
(i558,007)
(i576,065)
(i568,230)
Acquisitions,
net of cash acquired
(i105,979)
(i55,597)
(i167,692)
Net
proceeds from sale or disposition of property and other
i35,557
i29,812
i26,100
Investments
(i1,814)
(i2,011)
(i2,321)
Net
cash used in continuing operations
(i630,243)
(i603,861)
(i712,143)
Net
cash provided by discontinued operations
i—
i—
i1,236
Net
cash used in investing activities
(i630,243)
(i603,861)
(i710,907)
Financing
activities:
Issuance of short-term borrowings
i75,000
i169,977
i—
Repayment
of short-term borrowings
(i25,000)
(i170,000)
i—
Issuance
of long-term debt
i116,973
i599,455
i566,829
Repayment
of long-term debt
(i148,634)
(i468,917)
(i174,520)
Proceeds
from issuance of common stock
i3,385
i106,848
i—
Payments
of stock issuance costs
i—
i—
(i10)
Dividends
paid
(i166,405)
(i160,256)
(i154,573)
Repurchase
of common stock
i—
i—
(i5,020)
Tax
withholding on stock-based compensation
(i362)
(i3,015)
(i2,330)
Net
cash provided by (used in) financing activities
(i145,043)
i74,092
i230,376
Effect
of exchange rate changes on cash and cash equivalents
i—
i—
(i1)
Increase
(decrease) in cash and cash equivalents
(i6,912)
i12,511
i19,349
Cash
and cash equivalents - beginning of year
i66,459
i53,948
i34,599
Cash
and cash equivalents - end of year
$
i59,547
$
i66,459
$
i53,948
The
accompanying notes are an integral part of these consolidated financial statements.
64 MDU Resources Group, Inc. Form 10-K
Part II
Notes to Consolidated Financial Statements
Note 1
- iBasis of Presentation
i
The
abbreviations and acronyms used throughout are defined following the Notes to Consolidated Financial Statements. The consolidated financial statements of the Company include the accounts of the following businesses: electric, natural gas distribution, pipeline, construction materials and contracting, construction services and other. The electric and natural gas distribution businesses, as well as a portion of the pipeline business, are regulated. Construction materials and contracting, construction services and the other businesses, as well as a portion of the pipeline business, are non-regulated. For further descriptions of the Company's businesses, see Note 17.
On January 2, 2019, the
Company announced the completion of the Holding Company Reorganization, which resulted in Montana-Dakota becoming a subsidiary of the Company. The purpose of the reorganization was to make the public utility division into a subsidiary of the holding company, just as the other operating companies are wholly owned subsidiaries.
In March 2020, the World Health Organization declared the outbreak of COVID-19 a pandemic, and the President of the United States declared the COVID-19 outbreak as a national emergency. Governmental restrictions and guidelines implemented to control the spread of COVID-19 reduced commercial and interpersonal activity throughout the Company's areas
of operation. Most of the Company's products and services are considered essential and accordingly operations have been generally allowed to continue. The Company has experienced some inefficiency impacts, including operation suspensions and interruptions at some locations to carry out preventive measures or in response to instances of positive tests or quarantines. The Company has assessed the impacts of the COVID-19 pandemic on its results of operations for the twelve months ended December 31, 2020, and determined there were no material adverse impacts.
In the first quarter of 2020, the
Company recorded an out-of-period adjustment to correct the recognition of revenue on a construction contract, which was the result of an overstatement of operating revenue and receivables of $ii7.7/ million
and an understatement of operating expense and accounts payable of $ii1.2/ million
in the year ended December 31, 2019. This adjustment resulted in an after-tax reduction to net income of $i6.7 million in the first quarter of 2020. The Company evaluated the impact of the out-of-period adjustment and concluded it was not material to any previously issued interim and annual consolidated financial statements and the adjustment was not material to the three months ended March 31,
2020, or the twelve months ended December 31, 2020.
In the fourth quarter of 2020, the Company recorded an out-of-period adjustment to correct the recognition of net periodic benefit cost and other comprehensive income associated with the Company's benefit plans, which was the result of the previous overstatement of benefit plan expenses of $i6.5 million,
understatement of accumulated other comprehensive loss of $i2.7 million and overstatement of regulatory liabilities of $i3.8 million
from 2006 through 2020. This adjustment resulted in an after-tax increase to net income of $i4.4 million in the fourth quarter of 2020. The Company evaluated the impact of the out-of-period adjustment, individually and in the aggregate with the previously mentioned out-of-period adjustment, and concluded it was not material to any previously issued interim and annual consolidated financial statements and the adjustment was not material to the three and twelve months ended December 31,
2020.
Effective January 1, 2020, the Company adopted the requirements of the ASU on the measurement of credit losses on certain financial instruments following a modified retrospective approach, as further discussed in Note 2. As such, results for reporting periods beginning on January 1, 2020, are presented under the new guidance, while prior period amounts are not adjusted and continue to be reported in accordance with historic accounting. The Company's adoption of this guidance did not have a material impact on its financial reporting.
The assets and liabilities of the
Company's discontinued operations have been classified as held for sale and are included in prepayments and other current assets, noncurrent assets - other and other accrued liabilities on the Consolidated Balance Sheets and are not material to the financial statements for any period presented. The results and supporting activities are shown in income (loss) from discontinued operations on the Consolidated Statements of Income. Unless otherwise indicated, the amounts presented in the accompanying notes to the consolidated financial statements relate to the Company's continuing operations.
Management has also evaluated the impact of events occurring after December 31, 2020, up to the date of issuance of these consolidated financial statements.
/i
Principles
of consolidation
The consolidated financial statements were prepared in accordance with GAAP and include the accounts of the Company and its wholly-owned subsidiaries. All intercompany balances and transactions have been eliminated in consolidation, except for certain transactions related to the Company's regulated operations in accordance with GAAP. For more information on intercompany revenues, see Note 17.
The statements also include the Company's ownership interests in the assets, liabilities and expenses of jointly owned electric transmission and generating
facilities. See Note 19 for additional information.
MDU Resources Group, Inc. Form 10-K 65
Part II
i
Use
of estimates
The preparation of financial statements in conformity with GAAP requires the Company to make estimates and assumptions that affect the reported amounts of assets and liabilities, and disclosure of contingent assets and liabilities, at the date of the financial statements, as well as the reported amounts of revenues and expenses during the reporting period. Estimates are used for items such as long-lived assets and goodwill; fair values of acquired assets and liabilities under the acquisition method of accounting; aggregate reserves; property depreciable lives; tax provisions; revenue recognized using the cost-to-cost measure of progress for contracts; expected credit losses; environmental and other loss contingencies; regulatory assets expected
to be recovered in rates charged to customers; costs on construction contracts; unbilled revenues; actuarially determined benefit costs; asset retirement obligations; lease classification; present value of right-of-use assets and lease liabilities; and the valuation of stock-based compensation. As additional information becomes available, or actual amounts are determinable, the recorded estimates are revised. Consequently, operating results can be affected by revisions to prior accounting estimates.
Note 2 - iSignificant
Accounting Policies
i
New accounting standards
Recently adopted accounting standards
ASU 2016-13 - Measurement of Credit Losses on Financial Instruments In June 2016, the FASB issued guidance on the measurement of credit losses on certain financial instruments. The guidance introduced a new impairment model known as the current expected credit loss model
that replaced the incurred loss impairment methodology previously included under GAAP. This guidance required entities to present certain investments in debt securities, trade accounts receivable and other financial assets at their net carrying value of the amount expected to be collected on the financial statements. The Company adopted the guidance on January 1, 2020, using a modified retrospective approach.
The Company formed an implementation team to review and assess existing financial assets to identify and evaluate the financial assets subject to the new current expected credit loss model. The Company assessed the impact of the
guidance on its processes and internal controls and has identified and updated existing internal controls and processes to ensure compliance with the new guidance; such modifications were deemed insignificant. During the assessment phase, the Company identified the complete portfolio of assets subject to the current expected credit loss model. The Company determined the guidance did not have a material impact on its results of operations, financial position, cash flows or disclosures and did not record a material cumulative effect adjustment upon adoption. See Receivables and allowance for expected credit losses within this note for additional information on the Company's expected credit losses.
ASU
2018-13 - Changes to the Disclosure Requirements for Fair Value Measurement In August 2018, the FASB issued guidance on modifying the disclosure requirements on fair value measurements as part of the disclosure framework project. The guidance modified, among other things, the disclosures required for Level 3 fair value measurements, including the range and weighted average of significant unobservable inputs. The guidance removed, among other things, the disclosure requirement to disclose transfers between Levels 1 and 2. The Company adopted the guidance on January 1, 2020, and determined it did not have a material impact on its disclosures.
Recently issued accounting standards not yet adopted
ASU 2018-14 - Changes to the Disclosure Requirements
for Defined Benefit Plans In August 2018, the FASB issued guidance on modifying the disclosure requirements for employers that sponsor defined benefit pension or other postretirement plans as part of the disclosure framework project. The guidance removed disclosures that are no longer considered cost beneficial, clarifies the specific requirements of disclosures and added disclosure requirements identified as relevant. The guidance added, among other things, the requirement to include an explanation for significant gains and losses related to changes in benefit obligations for the period. The guidance removed, among other things, the disclosure requirement to disclose the amount of net periodic benefit costs to be amortized over the next fiscal year from accumulated other comprehensive income (loss) and the effects a one percentage point change in assumed health care cost trend rates will have on certain benefit components. The guidance was effective
for the Company on January 1, 2021, and must be applied on a retrospective basis. The Company determined the new guidance will not materially impact its consolidated financial statement disclosures.
ASU 2019-12 - Simplifying the Accounting for Income Taxes In December 2019, the FASB issued guidance on simplifying the accounting for income taxes by removing certain exceptions in ASC 740 and providing simplification amendments. The guidance removed exceptions on intraperiod tax allocations and reporting and provided simplification on accounting for franchise taxes, tax basis goodwill and tax law changes. The Company
adopted the guidance on January 1, 2021, and determined it did not have a material impact on its results of operations, financial position, cash flows and disclosures.
ASU 2020-04 - Reference Rate Reform In March 2020, the FASB issued optional guidance to ease the facilitation of the effects of reference rate reform on financial reporting. The guidance applies to certain contract modifications, hedging relationships and other transactions that reference LIBOR or another reference rate expected to be discontinued because of reference rate reform. LIBOR is expected to be retired with a full phase-out by the end of 2021 and replaced by new reference rates, which includes SOFR. The guidance can be applied beginning in the interim period that includes March
12, 2020, and cannot be applied to contract modifications or hedging relationships entered into or evaluated after December 31, 2022. The Company has updated its credit agreements to include language regarding the successor or alternate rate to LIBOR, and a review of other contracts and agreements is on-going. The Company does not expect the guidance to have a material impact on its results of operations, financial position, cash flows or disclosures.
66 MDU
Resources Group, Inc. Form 10-K
Part II
i
Cash and cash equivalents
The
Company considers all highly liquid investments purchased with an original maturity of three months or less to be cash equivalents.
Revenue recognition
i
Revenue is recognized when a performance obligation is satisfied by transferring control over a product or service to a customer. Revenue is measured based on consideration specified in a contract
with a customer and excludes any sales incentives and amounts collected on behalf of third parties. The Company is considered an agent for certain taxes collected from customers. As such, the Company presents revenues net of these taxes at the time of sale to be remitted to governmental authorities, including sales and use taxes.
The electric and natural gas distribution segments generate revenue from the sales of electric and natural gas products and services, which includes retail and transportation services. These segments establish a customer's retail or transportation service account based on the customer's application/contract for service, which indicates approval of
a contract for service. The contract identifies an obligation to provide service in exchange for delivering or standing ready to deliver the identified commodity; and the customer is obligated to pay for the service as provided in the applicable tariff. The product sales are based on a fixed rate that includes a base and per-unit rate, which are included in approved tariffs as determined by state or federal regulatory agencies. The quantity of the commodity consumed or transported determines the total per-unit revenue. The service provided, along with the product consumed or transported, are a single performance obligation because both are required in combination to successfully transfer the contracted product or service to the customer. Revenues are recognized over time as customers receive
and consume the products and services. The method of measuring progress toward the completion of the single performance obligation is on a per-unit output method basis, with revenue recognized based on the direct measurement of the value to the customer of the goods or services transferred to date. For contracts governed by the Company’s utility tariffs, amounts are billed monthly with the amount due between 15 and 22 days of receipt of the invoice depending on the applicable state’s tariff. For other contracts not governed by tariff, payment terms are net 30 days. At this time, the segment has no material obligations for returns, refunds or other similar obligations.
The
pipeline segment generates revenue from providing natural gas transportation, gathering and underground storage services, as well as other energy-related services to both third parties and internal customers, largely the natural gas distribution segment. The pipeline segment establishes a contract with a customer based upon the customer’s request for firm or interruptible natural gas transportation, storage or gathering service(s). The contract identifies an obligation for the segment to provide the requested service(s) in exchange for consideration from the customer over a specified term. Depending on the type of service(s) requested and contracted, the service provided may include transporting, gathering or storing an identified quantity of natural gas and/or standing ready to deliver or
store an identified quantity of natural gas. Natural gas transportation, gathering and storage revenues are based on fixed rates, which may include reservation fees and/or per-unit commodity rates. The services provided by the segment are generally treated as single performance obligations satisfied over time simultaneous to when the service is provided and revenue is recognized. Rates for the segment’s regulated services are based on its FERC approved tariff or customer negotiated rates, and rates for its non-regulated services are negotiated with its customers and set forth in the contract. For contracts governed by the company’s tariff, amounts are billed on or before the ninth business day of the following
month and the amount is due within 12 days of receipt of the invoice. For gathering contracts not governed by the tariff, amounts are due within 20 days of invoice receipt. For other contracts not governed by the tariff, payment terms are net 30 days. At this time, the segment has no material obligations for returns, refunds or other similar obligations.
The construction materials and contracting segment generates revenue from contracting services and construction materials sales. This segment focuses on the vertical integration of its contracting services with its construction materials to support the aggregate-based product lines. This segment provides contracting services to a customer when a contract
has been signed by both the customer and a representative of the segment obligating a service to be provided in exchange for the consideration identified in the contract. The nature of the services this segment provides generally includes integrating a set of services and related construction materials into a single project to create a distinct bundle of goods and services, which the Company evaluates to determine whether a separate performance obligation exists. The transaction price is the original contract price plus any subsequent change orders and variable consideration. Examples of variable consideration that exist in this segment's contracts
include liquidated damages; performance bonuses or incentives and penalties; claims; unapproved/unpriced change orders; and index pricing. The variable amounts usually arise upon achievement of certain performance metrics or change in project scope. The Company estimates the amount of revenue to be recognized on variable consideration using estimation methods that best predict the most likely amount of consideration the Company expects to be entitled to or expects to incur. The Company includes variable consideration in the estimated transaction price to the extent it is probable that a significant reversal of cumulative revenue recognized will not occur or when the uncertainty associated with the variable consideration is
resolved. Changes in circumstances could impact management's estimates made in determining the value of variable consideration recorded. The Company updates its estimate of the transaction price each reporting period and the effect of variable consideration on the transaction price is recognized as an adjustment to revenue on a cumulative catch-up basis. Revenue is recognized over time using an input method based on the cost-to-cost measure of progress on a project. This is the preferred method of measuring revenue because the costs incurred have been determined to represent the best indication of the overall progress toward the transfer of such goods or services promised to a customer. This segment also sells construction materials to third parties and internal customers. The contract for material
sales is the use of a sales order or an invoice, which includes the pricing and payment terms. All material contracts contain a single performance obligation for the delivery of a single distinct product or a distinct separately identifiable bundle of products and services. Revenue is recognized at a point in time when the performance obligation has been satisfied with the delivery of the products or services. The warranties associated with the sales are those consistent with a standard warranty that the product meets certain specifications for quality or those required by law. For most contracts, amounts billed to customers are due within 30 days of receipt. There are no material obligations for returns, refunds or other similar obligations.
MDU
Resources Group, Inc. Form 10-K 67
Part II
The construction services segment generates revenue from specialty contracting services which also includes the sale of construction equipment and other supplies. This segment provides specialty contracting services to a customer when a contract has been signed by both the customer and a representative of the segment obligating a service to be provided in exchange for the consideration identified in the contract.
The nature of the services this segment provides generally includes multiple promised goods and services in a single project to create a distinct bundle of goods and services, which the Company evaluates to determine whether a separate performance obligation exists. The transaction price is the original contract price plus any subsequent change orders and variable consideration. Examples of variable consideration that exist in this segment's contracts include claims, unapproved/unpriced change orders, bonuses, incentives, penalties and liquidated damages. The variable amounts usually arise upon achievement of certain performance metrics or change in project scope. The
Company estimates the amount of revenue to be recognized on variable consideration using estimation methods that best predict the most likely amount of consideration the Company expects to be entitled to or expects to incur. The Company includes variable consideration in the estimated transaction price to the extent it is probable that a significant reversal of cumulative revenue recognized will not occur or when the uncertainty associated with the variable consideration is resolved. Changes in circumstances could impact management's estimates made in determining the value of variable consideration recorded. The Company updates its estimate of the transaction price each reporting period and the effect of variable consideration
on the transaction price is recognized as an adjustment to revenue on a cumulative catch-up basis. Revenue is recognized over time using the input method based on the measurement of progress on a project. The input method is the preferred method of measuring revenue because the costs incurred have been determined to represent the best indication of the overall progress toward the transfer of such goods or services promised to a customer. This segment also sells construction equipment and other supplies to third parties and internal customers. The contract for these sales is the use of a sales order or invoice, which includes the pricing and payment terms. All such contracts include a single performance obligation for the delivery of a single distinct product or a distinct separately identifiable
bundle of products and services. Revenue is recognized at a point in time when the performance obligation has been satisfied with the delivery of the products or services. The warranties associated with the sales are those consistent with a standard warranty that the product meets certain specifications for quality or those required by law. For most contracts, amounts billed to customers are due within 30 days of receipt. There are no material obligations for returns, refunds or other similar obligations.
The Company recognizes all other revenues when services are rendered or goods are delivered.
Legal
costs
iThe Company expenses external legal fees as they are incurred.
Business combinations
iFor
all business combinations, the Company preliminarily allocates the purchase price of the acquisitions to the assets acquired and liabilities assumed based on their estimated fair values as of the acquisition dates and are considered provisional until final fair values are determined or the measurement period has passed. The Company expects to record adjustments as it accumulates the information needed to estimate the fair value of assets acquired and liabilities assumed, including working capital balances, estimated fair value of identifiable intangible assets, property, plant and equipment, total consideration and goodwill. The excess of the purchase price over the aggregate fair values is recorded as goodwill. The Company
calculated the fair value of the assets acquired in 2020 and 2019 using a market or cost approach (or a combination of both). Fair values for some of the assets were determined based on Level 3 inputs including estimated future cash flows, discount rates, growth rates, sales projections, retention rates and terminal values, all of which require significant management judgment and are susceptible to change. The final fair value of the net assets acquired may result in adjustments to the assets and liabilities, including goodwill, and will be made as soon as practical, but no later than 12 months from the respective acquisition dates. Any subsequent measurement period adjustments are not expected to have a material impact on the Company's results of operations.
Receivables
and allowance for expected credit losses
iReceivable consists primarily of trade receivables from the sale of goods and services, which are recorded at the invoiced amount, and contract assets, net of expected credit losses. For more information on contract assets, see Note 3.
The Company's trade receivables are all due in 12 months or less. The total balance of receivables past due 90 days or more was $i43.9 million and $i46.7
million at December 31, 2020 and 2019, respectively.
The Company's expected credit losses are determined through a review using historical credit loss experience, changes in asset specific characteristics, current conditions and reasonable and supportable future forecasts, among other specific account data, and is performed at least quarterly. The Company develops and documents its methodology to determine its allowance for expected credit losses at each of its reportable business segments. Risk characteristics used by the business segments may include customer mix, knowledge of customers and general economic conditions of the various local economies, among others.
Specific account balances are written off when management determines the amounts to be uncollectible.
The Company conducted additional analysis of its receivables and allowance for expected credit losses due to the impacts of COVID-19. As more customer balances enter arrears, further analysis supported increasing the uncollectible factors used in determining the expected credit losses of certain segments during 2020. Management has reviewed the balance reserved through the allowance for expected credit losses and believes it is reasonable.
68 MDU Resources Group, Inc. Form 10-K
Part
II
i
Details of the Company's expected credit losses were as follows:
Receivables also consist of accrued unbilled revenue representing revenues recognized in excess of amounts billed. Accrued unbilled revenue at MDU Energy Capital was $i94.0
million and $i100.8 million at December 31, 2020 and 2019, respectively.
i
Amounts representing
balances billed but not paid by customers under retainage provisions in contracts at December 31 were as follows:
2020
2019
(In thousands)
Short-term retainage*
$
i100,054
$
i75,590
Long-term
retainage**
i2,761
i14,228
Total
retainage
$
i102,815
$
i89,818
* Expected
to be paid within 12 months or less and included in receivables, net.
** Included in noncurrent assets - other.
/
Inventories and natural gas in storage
iNatural
gas in storage for the Company's regulated operations is generally valued at lower of cost or market using the last-in, first-out method or lower of cost or net realizable value using the average cost or first-in, first-out method. The majority of all other inventories are valued at the lower of cost or net realizable value using the average cost method. The portion of the cost of natural gas in storage expected to be used within 12 months was included in inventories. iInventories
at December 31 consisted of:
2020
2019
(In thousands)
Aggregates held for resale
$
i175,782
$
i147,723
Asphalt
oil
i28,238
i41,912
Materials
and supplies
i25,142
i22,512
Merchandise
for resale
i21,087
i22,232
Natural
gas in storage (current)
i21,919
i22,058
Other
i18,999
i21,970
Total
$
i291,167
$
i278,407
The
remainder of natural gas in storage, which largely represents the cost of gas required to maintain pressure levels for normal operating purposes, was included in noncurrent assets - other and was $i47.5 million and $i48.4 million
at December 31, 2020 and 2019, respectively.
MDU Resources Group, Inc. Form 10-K 69
Part II
Property, plant and equipment
iAdditions
to property, plant and equipment are recorded at cost. When regulated assets are retired, or otherwise disposed of in the ordinary course of business, the original cost of the asset is charged to accumulated depreciation. With respect to the retirement or disposal of all other assets, the resulting gains or losses are recognized as a component of income. The Company is permitted to capitalize AFUDC on regulated construction projects and to include such amounts in rate base when the related facilities are placed in service. In addition, the Company capitalizes interest, when applicable, on certain construction projects associated with its other operations.iThe
amount of AFUDC for the years ended December 31 was as follows:
2020
2019
2018
(In thousands)
AFUDC - borrowed
$
i2,640
$
i2,807
$
i2,290
AFUDC
- equity
$
i1,270
$
i698
$
i1,897
Generally,
property, plant and equipment are depreciated on a straight-line basis over the average useful lives of the assets, except for depletable aggregate reserves, which are depleted based on the units-of-production method. The Company collects removal costs for plant assets in regulated utility rates. These amounts are recorded as regulatory liabilities on the Consolidated Balance Sheets.
Impairment of long-lived assets
iThe
Company reviews the carrying values of its long-lived assets, excluding goodwill, whenever events or changes in circumstances indicate that such carrying values may not be recoverable. The determination of whether an impairment has occurred is based on an estimate of undiscounted future cash flows attributable to the assets, compared to the carrying value of the assets. If impairment has occurred, the amount of the impairment recognized is determined by estimating the fair value of the assets and recording a loss if the carrying value is greater than the fair value. The impairments are recorded in operation and maintenance expense on the Consolidated Statements of Income.
iiiNo//
significant impairment losses were recorded in 2020, 2019 or 2018. Unforeseen events and changes in circumstances could require the recognition of impairment losses at some future date.
Regulatory assets and liabilities
i
The Company's regulated businesses are subject to various state and federal agency regulations. The accounting policies followed by these businesses
are generally subject to the Uniform System of Accounts of the FERC as well as the provisions of ASC 980 - Regulated Operations. These accounting policies differ in some respects from those used by the Company's non-regulated businesses.
The Company's regulated businesses account for certain income and expense items under the provisions of regulatory accounting, which requires these businesses to defer as regulatory assets or liabilities certain items that would have otherwise been reflected as expense or income, respectively. The Company records regulatory assets or liabilities at the time the
Company determines the amounts to be recoverable in current or future rates. Regulatory assets and liabilities are being amortized consistently with the regulatory treatment established by the FERC and the applicable state public service commission. See Note 6 for more information regarding the nature and amounts of these regulatory deferrals.
Natural gas costs recoverable or refundable through rate adjustments
iUnder
the terms of certain orders of the applicable state public service commissions, the Company is deferring natural gas commodity, transportation and storage costs that are greater or less than amounts presently being recovered through its existing rate schedules. Such orders generally provide that these amounts are recoverable or refundable through rate adjustments. Natural gas costs refundable through rate adjustments were $i18.6 million and $i23.8 million
at December 31, 2020 and 2019, respectively, which was included in regulatory liabilities due within one year on the Consolidated Balance Sheets. Natural gas costs recoverable through rate adjustments were $i64.0 million and $i89.2 million
at December 31, 2020 and 2019, respectively, which was included in current regulatory assets and noncurrent assets - regulatory assets on the Consolidated Balance Sheets.
Goodwill
iGoodwill represents the excess of the purchase price over the fair value of identifiable net tangible and intangible assets acquired in a business
combination. Goodwill is required to be tested for impairment annually, which the Company completes in the fourth quarter, or more frequently if events or changes in circumstances indicate that goodwill may be impaired.
The Company has determined that the reporting units for its goodwill impairment test are its operating segments, or components of an operating segment, that constitute a business for which discrete financial information is available and for which segment management regularly reviews the operating results. For more information on the Company's operating segments, see Note 17. Goodwill impairment, if any, is measured by comparing the fair value of each reporting
unit to its carrying value. If the fair value of a reporting unit exceeds its carrying value, the goodwill of the reporting unit is not impaired. If the carrying value of a reporting unit exceeds its fair value, the Company must record an impairment loss for the amount that the carrying value of the reporting unit, including goodwill, exceeds the fair value of the reporting unit. For the years ended December 31, 2020, 2019 and 2018, there were iiino//
impairment losses recorded. The Company performed its annual goodwill impairment test in the fourth quarter of 2020 and determined the fair value substantially exceeded the carrying value at all reporting units at October 31, 2020.
70 MDU Resources Group, Inc. Form 10-K
Part II
Investments
iThe
Company's investments include the cash surrender value of life insurance policies, an insurance contract, mortgage-backed securities and U.S. Treasury securities. The Company measures its investment in the insurance contract at fair value with any unrealized gains and losses recorded on the Consolidated Statements of Income. The Company has not elected the fair value option for its mortgage-backed securities and U.S. Treasury securities and, as a result, the unrealized gains and losses on these investments are recorded in accumulated other comprehensive income (loss). For more information, see Notes 8 and 18.
Derivative
instruments
iThe Company enters into commodity price derivative contracts in order to minimize the price volatility associated with natural gas costs at its natural gas distribution segment. These derivatives are not designated as hedging instruments and are recorded in the Consolidated Balance Sheets at fair value, as discussed in Note 8. Changes in the fair value of these derivatives along with
any contract settlements are recorded each period in regulatory assets or liabilities in accordance with regulatory accounting. The Company does not enter into any derivatives for trading or other speculative purposes.
In 2017, the WUTC issued a requirement for gas providers to implement robust, risk-responsive hedging programs in order to minimize volatility in natural gas prices for natural gas utility customers and in 2019, the Company implemented policies and procedures that met these requirements. During 2020 and 2019, the Company entered into commodity price derivative contracts
securing the purchase of i1.4 million MMBtu and i535,000
MMBtu of natural gas, respectively.
Leases
i
Lease liabilities and their corresponding right-of-use assets are recorded based on the present value of lease payments over the expected lease term. The Company recognizes leases with an original lease term of 12 months or less in income on a straight-line basis over the term of the lease and does not recognize a corresponding
right-of-use asset or lease liability. The Company determines the lease term based on the non-cancelable and cancelable periods in each contract. The non-cancelable period consists of the term of the contract that is legally enforceable and cannot be canceled by either party without incurring a significant penalty. The cancelable period is determined by various factors that are based on who has the right to cancel a contract. If only the lessor has the right to cancel the contract, the
Company will assume the contract will continue. If the lessee is the only party that has the right to cancel the contract, the Company looks to asset, entity and market-based factors. If both the lessor and the lessee have the right to cancel the contract, the Company assumes the contract will not continue.
The discount rate used to calculate the present value of the lease liabilities is based upon the implied
rate within each contract. If the rate is unknown or cannot be determined, the Company uses an incremental borrowing rate, which is determined by the length of the contract, asset class and the Company's borrowing rates, as of the commencement date of the contract.
Asset retirement obligations
iThe
Company records the fair value of a liability for an asset retirement obligation in the period in which it is incurred. When the liability is initially recorded, the Company capitalizes a cost by increasing the carrying amount of the related long-lived asset. Over time, the liability is accreted to its present value each period and the capitalized cost is depreciated over the useful life of the related asset. Upon settlement of the liability, the Company either settles the obligation for the recorded amount or incurs a gain or loss at its non-regulated operations or incurs a regulatory asset or liability at its regulated operations.
Stock-based
compensation
iThe Company determines compensation expense for stock-based awards based on the estimated fair values at the grant date and recognizes the related compensation expense over the vesting period. The Company uses the straight-line amortization method to recognize compensation expense related to restricted stock, which only has a service
condition. This method recognizes stock compensation expense on a straight-line basis over the requisite service period for the entire award. The Company recognizes compensation expense related to performance awards that vest based on performance metrics and service conditions on a straight-line basis over the service period. Inception-to-date expense is adjusted based upon the determination of the potential achievement of the performance target at each reporting date. The Company recognizes compensation expense related to performance awards with market-based performance metrics on a straight-line basis over the requisite service period.
The Company records the compensation
expense for performance share awards using an estimated forfeiture rate. The estimated forfeiture rate is calculated based on an average of actual historical forfeitures. The Company also performs an analysis of any known factors at the time of the calculation to identify any necessary adjustments to the average historical forfeiture rate. At the time actual forfeitures become more than estimated forfeitures, the Company records compensation expense using actual forfeitures.
MDU Resources Group, Inc. Form 10-K 71
Part
II
Earnings per share
iBasic earnings per share were computed by dividing net income by the weighted average number of shares of common stock outstanding during the year. Diluted earnings per share were computed by dividing net income by the total of the weighted average number of shares of common stock outstanding during the year, plus the effect of nonvested performance share awards and restricted stock
units. Common stock outstanding includes issued shares less shares held in treasury. Net income was the same for both the basic and diluted earnings per share calculations. iA reconciliation of the weighted average common shares outstanding used in the basic and diluted earnings per share calculation was as follows:
2020
2019
2018
(In
thousands)
Weighted average common shares outstanding - basic
i200,502
i198,612
i195,720
Effect
of dilutive performance share awards
i69
i14
i430
Weighted
average common shares outstanding - diluted
i200,571
i198,626
i196,150
Shares
excluded from the calculation of diluted earnings per share
i164
i164
i10
Income
taxes
i
The Company provides deferred federal and state income taxes on all temporary differences between the book and tax basis of the Company's assets and liabilities by using enacted tax rates in effect for the year in which the differences are expected to reverse. The effect of a change in tax rates on deferred tax assets and liabilities is recognized in income in the period that includes the enactment date. Excess deferred income tax balances associated
with the Company's rate-regulated activities have been recorded as a regulatory liability and are included in other liabilities. These regulatory liabilities are expected to be reflected as a reduction in future rates charged to customers in accordance with applicable regulatory procedures.
The Company uses the deferral method of accounting for investment tax credits and amortizes the credits on regulated electric and natural gas distribution plant over various periods that conform to the ratemaking treatment prescribed by the applicable state public service commissions.
iThe
Company records uncertain tax positions in accordance with accounting guidance on accounting for income taxes on the basis of a two-step process in which (1) the Company determines whether it is more-likely-than-not that the tax position will be sustained on the basis of the technical merits of the position and (2) for those tax positions that meet the more-likely-than-not recognition threshold, the Company recognizes the largest amount of the tax benefit that is more than i50
percent percent likely to be realized upon ultimate settlement with the related tax authority. Tax positions that do not meet the more-likely-than-not criteria are reflected as a tax liability. The Company recognizes interest and penalties accrued related to unrecognized tax benefits in income taxes./
i
Variable
interest entities
The Company evaluates its arrangements and contracts with other entities to determine if they are VIEs and if so, if the Company is the primary beneficiary. GAAP provides a framework for identifying VIEs and determining when a company should include the assets, liabilities, noncontrolling interest and results of activities of a VIE in its consolidated financial statements.
A VIE should be consolidated if a party with an ownership, contractual or other financial interest in the VIE (a variable interest holder) has the power to direct the VIE's most significant activities and the obligation to absorb losses or right to receive
benefits of the VIE that could be significant to the VIE. A variable interest holder that consolidates the VIE is called the primary beneficiary. Upon consolidation, the primary beneficiary generally must initially record all of the VIE's assets, liabilities and noncontrolling interests at fair value and subsequently account for the VIE as if it were consolidated.
The Company's evaluation of whether it qualifies as the primary beneficiary of a VIE involves significant judgments, estimates and assumptions and includes a qualitative analysis of the activities that most significantly impact the VIE's economic performance and whether the Company has the power to direct those activities, the design of the entity, the rights of the parties and the purpose of the arrangement.
Revenue is recognized when a performance obligation is satisfied by transferring control over a product or service to a customer. Revenue is measured based on consideration specified in a contract with a customer and excludes any sales incentives and amounts collected on behalf of third parties. The
Company is considered an agent for certain taxes collected from customers. As such, the Company presents revenues net of these taxes at the time of sale to be remitted to governmental authorities, including sales and use taxes.
As part of the adoption of ASC 606 - Revenue from Contracts with Customers, the Company elected the practical expedient to recognize the incremental costs of obtaining a contract as an expense when incurred if the amortization period of the asset that the
Company otherwise would have recognized is 12 months or less.
72 MDU Resources Group, Inc. Form 10-K
Part II
i
Disaggregation
In
the following table, revenue is disaggregated by the type of customer or service provided. The Company believes this level of disaggregation best depicts how the nature, amount, timing and uncertainty of revenue and cash flows are affected by economic factors. The table also includes a reconciliation of the disaggregated revenue by reportable segments. For more information on the Company's business segments, see Note 17.
Presented
in the previous tables are intrasegment revenues within the construction materials and contracting segment to highlight the focus on vertical integration as this segment sells materials to both third parties and internal customers. Due to consolidation requirements, these revenues must be eliminated against construction materials to arrive at the external operating revenue total for the segment.
The timing of revenue recognition may differ from the timing of invoicing to customers. The timing of invoicing to customers does not necessarily correlate with the timing of revenues being recognized under the cost‐to‐cost method of accounting. Contracts from contracting services are billed as
work progresses in accordance with agreed upon contractual terms. Generally, billing to the customer occurs contemporaneous to revenue recognition. A variance in timing of the billings may result in a contract asset or a contract liability. A contract asset occurs when revenues are recognized under the cost-to-cost measure of progress, which exceeds amounts billed on uncompleted contracts. Such amounts will be billed as standard contract terms allow, usually based on various measures of performance or achievement. A contract
liability occurs when there are billings in excess of revenues recognized under the cost-to-cost measure of progress on uncompleted contracts. Contract liabilities decrease as revenue is recognized from the satisfaction of the related performance obligation.
i
The changes in contract assets
and liabilities were as follows:
The Company recognized a net increase in revenues of $i58.8 million
and $i44.1 million for the years ended December 31, 2020 and 2019, respectively, from performance obligations satisfied in prior periods.
74 MDU Resources
Group, Inc. Form 10-K
Part II
Remaining performance obligations
The remaining performance obligations, also referred to as backlog, at the construction materials and contracting and construction services segments include unrecognized revenues that the Company reasonably expects to be realized. These unrecognized revenues can include: projects that have a written award, a letter of intent, a notice to proceed, an agreed upon work order to perform work
on mutually accepted terms and conditions and change orders or claims to the extent management believes additional contract revenues will be earned and are deemed probable of collection. Excluded from remaining performance obligations are potential orders under master service agreements. The majority of the Company's construction contracts have an original duration of less than two years.
The remaining performance obligations at the pipeline segment include firm transportation and storage contracts with fixed pricing and fixed volumes. The
Company has applied the practical expedient that does not require additional disclosures for contracts with an original duration of less than 12 months to certain firm transportation and non-regulated contracts. The Company's firm transportation and firm storage contracts included in the remaining performance obligations have weighted average remaining durations of approximately five and one years, respectively.
At December 31, 2020, the Company's
remaining performance obligations were $i2.1 billion. The Company expects to recognize the following revenue amounts in future periods related to these remaining performance obligations: $i1.6 billion
within the next i12 months or less; $i298.8 million within the next i13
to 24 months; and $i234.3 million in i25 months or more.
Note 4
- iBusiness Combinations
The following acquisitions were accounted for as business combinations in accordance with ASC 805 - Business Combinations. The results of the business combinations have been included in the Company's Consolidated Financial Statements beginning on the acquisition date. Pro forma financial amounts reflecting the effects of the business combinations are not presented, as none of
these business combinations, individually or in the aggregate, were material to the Company's financial position or results of operations.
The acquisitions are also subject to customary adjustments based on, among other things, the amount of cash, debt and working capital in the business as of the closing date. The amounts included in the Consolidated Balance Sheets for these adjustments are considered provisional until final settlement has occurred.
The following acquisitions were made during 2020 and 2019 at the construction materials and contracting segment:
•In December 2020, the Company acquired the assets of McMurry Ready-Mix Co., an aggregates and
concrete supplier in Wyoming.
•In February 2020, the Company acquired the assets of Oldcastle Infrastructure Spokane, a prestressed-concrete business in Washington.
•In December 2019, the Company acquired the assets Roadrunner Ready Mix, Inc., a provider of ready-mixed concrete in Idaho.
•In March 2019, the Company acquired Viesko Redi-Mix, Inc., a provider of ready-mixed concrete in Oregon.
The following acquisitions were made during 2020 and 2019 at the construction services
segment:
•In February 2020, the Company acquired PerLectric, Inc., an electrical construction company in Virginia.
•In September 2019, the Company acquired the assets of Pride Electric, Inc., an electrical construction company in Washington.
The total purchase price for acquisitions that occurred in 2020 was $i110.2 million,
subject to certain adjustments, with cash acquired totaling $i1.7 million. The purchase price includes consideration paid of $i106.0
million and $i2.5 million of indemnity holdback liabilities. The amounts allocated to the aggregated assets acquired and liabilities assumed during 2020 were as follows: $i54.8 million
to current assets; $i27.1 million to property, plant and equipment; $i33.6 million
to goodwill; $i19.0 million to other intangible assets; $i22.6 million
to current liabilities; $i300,000 to noncurrent liabilities - other and $i1.4
million to asset retirement obligations. At December 31, 2020, the purchase price adjustments for Oldcastle Infrastructure Spokane had been settled and no material adjustments were made to the provisional accounting. Purchase price allocations for PerLectric, Inc. and McMurry Ready-Mix Co. are preliminary and will be finalized within 12 months of the respective acquisition dates. The Company issued debt to finance these acquisitions.
In 2019, the gross aggregate consideration for acquisitions was $i56.8 million,
subject to certain adjustments, and includes $i1.2 million of debt assumed. The amounts allocated to the aggregated assets acquired and liabilities assumed during 2019 were as follows: $i15.8
million to current assets; $i16.7 million to property, plant and equipment; $i23.1
million to goodwill; $i6.7 million to other intangible assets; $i500,000
to noncurrent assets - other; $i5.9 million to current liabilities and $i100,000
to noncurrent liabilities - other. At December 31, 2020, the purchase price adjustments for all 2019 acquisitions had been settled and no material adjustments were made to the provisional accounting. The Company issued debt and equity securities to finance these acquisitions.
During 2020, measurement period adjustments were made to previously reported provisional amounts, which increased goodwill by $i391,000.
Costs
incurred for acquisitions are included in operation and maintenance expense on the Consolidated Statements of Income and were not material for the years ended December 31, 2020 and 2019.
MDU Resources Group, Inc. Form 10-K 75
Part II
Note
5 - iProperty, Plant and Equipment
i
Property, plant and equipment at December 31 was as follows:
2020
2019
Weighted Average Depreciable Life
in Years
(Dollars in thousands, where applicable)
Regulated:
Electric:
Generation
$
i1,133,390
$
i1,139,059
i48
Distribution
i464,442
i443,780
i46
Transmission
i524,155
i445,485
i64
Construction
in progress
i61,766
i66,664
—
Other
i139,650
i132,157
i14
Natural
gas distribution:
Distribution
i2,302,121
i2,133,249
i47
Transmission
i104,695
i104,401
i51
Storage
i33,014
i31,484
i24
General
i198,211
i191,446
i14
Construction
in progress
i16,836
i39,506
—
Other
i213,976
i188,037
i16
Pipeline:
Transmission
i665,567
i636,796
i46
Gathering
i—
i35,661
—
Storage
i52,632
i50,001
i53
Construction
in progress
i46,690
i22,597
—
Other
i49,640
i48,340
i17
Non-regulated:
Pipeline:
Gathering
i—
i31,148
—
Construction
in progress
i4
i154
—
Other
i7,164
i9,518
i11
Construction
materials and contracting:
Land
i132,948
i127,729
—
Buildings
and improvements
i130,417
i122,064
i21
Machinery,
vehicles and equipment
i1,284,604
i1,180,343
i12
Construction
in progress
i23,803
i25,018
—
Aggregate
reserves
i456,704
i455,408
**
Construction
services:
Land
i7,218
i7,146
—
Buildings
and improvements
i41,674
i31,735
i25
Machinery,
vehicles and equipment
i163,080
i156,537
i7
Other
i8,824
i17,952
i4
Other:
Land
i2,648
i2,648
—
Other
i34,897
i32,565
i12
Less
accumulated depreciation, depletion and amortization
i3,133,831
i2,991,486
Net
property, plant and equipment
$
i5,166,939
$
i4,917,142
*Depleted
on the units-of-production method based on recoverable aggregate reserves.
/
76 MDU Resources Group, Inc. Form 10-K
Part II
Note 6
- iRegulatory Assets and Liabilities
ii
The
following table summarizes the individual components of unamortized regulatory assets and liabilities as of December 31:
Estimated Recovery or Refund Period
*
2020
2019
(In
thousands)
Regulatory assets:
Current:
Natural gas costs recoverable through rate adjustments
iUp to 1 year
$
i42,481
$
i42,823
Cost
recovery mechanisms
iUp to 1 year
i10,645
i6,288
Conservation
programs
iUp to 1 year
i7,117
i6,963
Other
iUp
to 1 year
i8,284
i7,539
i68,527
i63,613
Noncurrent:
Pension
and postretirement benefits
i**
i155,942
i157,069
Plant
costs/asset retirement obligations
iOver plant lives
i71,740
i66,000
Plant
to be retired
i-
i65,919
i32,931
Manufactured
gas plant sites remediation
i-
i26,429
i15,126
Natural
gas costs recoverable through rate adjustments
iUp to 2 years
i21,539
i46,381
Cost
recovery mechanisms
iUp to 10 years
i16,245
i13,108
Taxes
recoverable from customers
iOver plant lives
i10,785
i11,486
Long-term
debt refinancing costs
iUp to 40 years
i4,426
i4,286
Other
iUp
to 18 years
i6,356
i7,397
i379,381
i353,784
Total
regulatory assets
$
i447,908
$
i417,397
Regulatory
liabilities:
Current:
Natural gas costs refundable through rate adjustments
iUp to 1 year
$
i18,565
$
i23,825
Electric
fuel and purchased power deferral
iUp to 1 year
i3,667
i5,824
Taxes
refundable to customers
iUp to 1 year
i3,557
i3,472
Other
iUp
to 1 year
i5,661
i9,814
i31,450
i42,935
Noncurrent:
Taxes
refundable to customers
iOver plant lives
i227,850
i246,034
Plant
removal and decommissioning costs
iOver plant lives
i167,171
i173,722
Pension
and postretirement benefits
i**
i16,989
i18,065
Other
iUp
to 21 years
i16,065
i9,549
i428,075
i447,370
Total
regulatory liabilities
$
i459,525
$
i490,305
Net
regulatory position
$
(i11,617)
$
(i72,908)
*Estimated
recovery or refund period for amounts currently being recovered or refunded in rates to customers.
** Recovered as expense is incurred or cash contributions are made.
//
As of December 31, 2020 and 2019, approximately $i332.5 million
and $i276.5 million, respectively, of regulatory assets were not earning a rate of return but are expected to be recovered from customers in future rates. These assets are largely comprised of the unfunded portion of pension and postretirement benefits, asset retirement obligations, accelerated depreciation on plant to be retired and the estimated future cost of manufactured gas plant site remediation.
In
2019, the Company experienced increased natural gas costs in Washington from the rupture of the Enbridge pipeline in Canada in late 2018. As a result, the Company requested, and the WUTC approved, recovery of the balance of natural gas costs recoverable related to this period of time over three years rather than its normal one-year recovery period.
In February 2019, the Company announced that it intends to retire one aging coal-fired electric generating unit in March 2021 and two units in early 2022. The Company has accelerated the depreciation related to these facilities in property, plant and equipment
and has recorded the difference between the accelerated depreciation, in accordance with GAAP, and the depreciation approved for rate-making purposes as regulatory assets. The Company expects to recover the regulatory assets related to the plants to be retired in future rates.
MDU Resources Group, Inc. Form 10-K 77
Part II
If,
for any reason, the Company's regulated businesses cease to meet the criteria for application of regulatory accounting for all or part of their operations, the regulatory assets and liabilities relating to those portions ceasing to meet such criteria would be removed from the balance sheet and included in the statement of income or accumulated other comprehensive income (loss) in the period in which the discontinuance of regulatory accounting occurs.
Note 7 - iGoodwill
and Other Intangible Assets
i
The changes in the carrying amount of goodwill were as follows:
Other
amortizable intangible assets at December 31 were as follows:
2020
2019
(In thousands)
Customer relationships
$
i28,836
$
i17,958
Less
accumulated amortization
i6,887
i6,268
i21,949
i11,690
Noncompete
agreements
i3,941
i3,439
Less
accumulated amortization
i2,309
i1,957
i1,632
i1,482
Other
i12,927
i8,094
Less
accumulated amortization
i11,012
i6,020
i1,915
i2,074
Total
$
i25,496
$
i15,246
/
The
previous tables include goodwill and intangible assets associated with the business combinations completed during 2020 and 2019. For more information related to these business combinations, see Note 4.
Amortization expense for amortizable intangible assets for the years ended December 31, 2020, 2019 and 2018, was $i9.0 million, $i2.4 million
and $i1.2 million, respectively. iThe amounts of estimated amortization
expense for identifiable intangible assets as of December 31, 2020, were:
2021
2022
2023
2024
2025
Thereafter
(In
thousands)
Amortization expense
$
i4,911
$
i4,394
$
i4,121
$
i3,799
$
i1,862
$
i6,409
78 MDU
Resources Group, Inc. Form 10-K
Part II
Note 8 - iFair Value
Measurements
The Company measures its investments in certain fixed-income and equity securities at fair value with changes in fair value recognized in income. The Company anticipates using these investments, which consist of an insurance contract, to satisfy its obligations under its unfunded, nonqualified defined benefit plans for executive officers and certain key management employees, and invests in these fixed-income and equity securities for the purpose of earning investment returns and capital appreciation. These investments, which totaled $i100.1 million
and $i87.0 million at December 31, 2020 and 2019, respectively, are classified as investments on the Consolidated Balance Sheets. The net unrealized gains on these investments for the years ended December 31, 2020 and 2019, were $i13.1 million
and $i13.2 million, respectively. The net unrealized loss on these investments for the year ended December 31, 2018, was $i3.6 million.
The change in fair value, which is considered part of the cost of the plan, is classified in other income on the Consolidated Statements of Income.
The Company did not elect the fair value option, which records gains and losses in income, for its available-for-sale securities, which include mortgage-backed securities and U.S. Treasury securities. These available-for-sale securities are recorded at fair value and are classified as investments on the Consolidated Balance Sheets. Unrealized gains or losses are recorded in accumulated other comprehensive income (loss). iDetails
of available-for-sale securities were as follows:
Fair
value is defined as the price that would be received to sell an asset or paid to transfer a liability (an exit price) in an orderly transaction between market participants at the measurement date. The fair value ASC establishes a hierarchy for grouping assets and liabilities, based on the significance of inputs. The estimated fair values of the Company's assets and liabilities measured on a recurring basis are determined using the market approach.
i
The
Company's assets measured at fair value on a recurring basis were as follows:
*The
insurance contract invests approximately i57 percent in fixed-income investments, i18 percent
in common stock of large-cap companies, i9 percent in common stock of mid-cap companies, i9 percent in common stock of small-cap companies,
i5 percent in target date investments and i2 percent in cash equivalents.
* The
insurance contract invests approximately i51 percent in fixed-income investments, i23 percent
in common stock of large-cap companies, i12 percent in common stock of mid-cap companies, i10 percent in common stock of small-cap companies,
i3 percent in target date investments and i1 percent in cash equivalents.
The
Company's money market funds are valued at the net asset value of shares held at the end of the period, based on published market quotations on active markets, or using other known sources including pricing from outside sources. The estimated fair value of the Company's mortgage-backed securities and U.S. Treasury securities are based on comparable market transactions, other observable inputs or other sources, including pricing from outside sources. The estimated fair value of the Company's insurance contract is based on contractual cash surrender values that are determined primarily by investments in managed separate accounts of the insurer. These amounts approximate fair value. The managed separate accounts are
valued based on other observable inputs or corroborated market data.
Though the Company believes the methods used to estimate fair value are consistent with those used by other market participants, the use of other methods or assumptions could result in a different estimate of fair value.
The Company applies the provisions of the fair value measurement standard to its nonrecurring, non-financial measurements, including long-lived asset impairments. These assets are not measured at fair value on an ongoing basis but are subject to fair value adjustments only in certain circumstances. The Company reviews the carrying value of its long-lived
assets, excluding goodwill, whenever events or changes in circumstances indicate that such carrying amounts may not be recoverable.
In the second quarter of 2019, the Company reviewed a non-utility investment at its electric and natural gas distribution segments for impairment. This was a cost-method investment and was written down to izero using the income approach to determine its fair value, requiring the
Company to record a write-down of $i2.0 million, before tax. The fair value of this investment was categorized as Level 3 in the fair value hierarchy. The reduction is reflected in investments on the Consolidated Balance Sheet, as well as within other income on the Consolidated Statement of Income.
The estimated fair value of the Company's Level 2 commodity derivative instruments is based on futures prices, volatility and time to maturity, among
other things. Counterparty statements are utilized to determine the value of the commodity derivative instruments and are reviewed and corroborated using various methodologies and significant observable inputs. The Company's and the counterparties' nonperformance risk is also evaluated.
The Company performed a fair value assessment of the assets acquired and liabilities assumed in the business combinations that occurred during 2020 and 2019. For more information on these Level 2 and Level 3 fair value measurements, see Notes 2 and 4.
The Company's long-term debt is not measured at fair value on the Consolidated Balance Sheets and the fair
value is being provided for disclosure purposes only. The fair value was categorized as Level 2 in the fair value hierarchy and was based on discounted future cash flows using current market interest rates. iThe estimated fair value of the Company's Level 2 long-term debt at December 31 was as follows:
2020
2019
(In
thousands)
Carrying Amount
$
i2,213,130
$
i2,243,107
Fair
Value
$
i2,537,289
$
i2,418,631
The
carrying amounts of the Company's remaining financial instruments included in current assets and current liabilities approximate their fair values.
80 MDU Resources Group, Inc. Form 10-K
Part II
Note 9
- iDebt
Certain debt instruments of the Company's subsidiaries, including those discussed later, contain restrictive and financial covenants and cross-default provisions. In order to borrow under the debt agreements, the subsidiary companies must be in compliance with the applicable covenants and certain other conditions, all of which the subsidiaries,
as applicable, were in compliance with at December 31, 2020. In the event the subsidiaries do not comply with the applicable covenants and other conditions, alternative sources of funding may need to be pursued.
i
The following table summarizes the outstanding revolving credit facilities of the Company's subsidiaries:
(a) The
commercial paper program is supported by a revolving credit agreement with various banks (provisions allow for increased borrowings, at the option of Montana-Dakota on stated conditions, up to a maximum of $i225.0 million). There were ino
amounts outstanding under the revolving credit agreement.
(b) Certain provisions allow for increased borrowings, up to a maximum of $i125.0 million.
(c) Outstanding letter(s) of credit reduce the amount available under the credit agreement.
(d) Certain provisions allow for increased borrowings, up to a maximum of $i110.0 million.
(e) The
commercial paper program is supported by a revolving credit agreement with various banks (provisions allow for increased borrowings, at the option of Centennial on stated conditions, up to a maximum of $i700.0 million). There were ino
amounts outstanding under the revolving credit agreement.
/
The respective commercial paper programs are supported by revolving credit agreements. While the amount of commercial paper outstanding does not reduce available capacity under the respective revolving credit agreements, Montana-Dakota and Centennial do not issue commercial paper in an aggregate amount exceeding the available capacity under their credit agreements. The commercial paper borrowings may vary during the period, largely the result of fluctuations in working capital requirements due to the seasonality of certain operations of the
Company's subsidiaries.
Short-term debt
Montana-Dakota On April 8, 2020, Montana-Dakota entered into a $i75.0 million term loan agreement with a LIBOR-based variable interest rate and a maturity date of April 7, 2021. At December 31, 2020, Montana-Dakota
had $i50.0 million outstanding under the agreement. The agreement contains customary covenants and provisions, including a covenant of Montana-Dakota not to permit, at any time, the ratio of total debt to total capitalization to be greater than i65 percent.
The covenants also include certain restrictions on the sale of certain assets, loans and investments.
Long-term debt
Long-term Debt OutstandingiLong-term debt outstanding was as follows:
Other
notes due on dates ranging from July 15, 2021 to November 30, 2038
i.75
%
i4,034
i29,117
Less
unamortized debt issuance costs
i5,803
i7,010
Less
discount
i1
i50
Total
long-term debt
i2,213,130
i2,243,107
Less
current maturities
i1,555
i16,540
Net
long-term debt
$
i2,211,575
$
i2,226,567
Montana-Dakota
On January 1, 2019, the Company's revolving credit agreement and commercial paper program became Montana-Dakota's revolving credit agreement and commercial paper program as a result of the Holding Company Reorganization. The outstanding balance of the revolving credit agreement was also transferred to Montana-Dakota. All of the related terms and covenants of the credit agreements remained the same.
Montana-Dakota's revolving credit agreement supports its commercial paper program. Commercial paper borrowings under this agreement are classified as long-term debt as they are intended to be refinanced on a long-term basis through continued commercial paper borrowings. The credit agreement contains customary covenants and provisions, including covenants of Montana-Dakota not to
permit, as of the end of any fiscal quarter,
MDU Resources Group, Inc. Form 10-K 81
Part II
the ratio of funded debt to total capitalization (determined on a consolidated basis) to be greater than i65 percent.
Other covenants include limitations on the sale of certain assets and on the making of certain loans and investments.
Montana-Dakota's ratio of total debt to total capitalization at December 31, 2020, was i49 percent.
Cascade Any borrowings under the revolving credit agreement are classified as long-term debt as they are intended to be refinanced on a long-term basis through continued borrowings. The credit agreement contains customary
covenants and provisions, including a covenant of Cascade not to permit, at any time, the ratio of total debt to total capitalization to be greater than i65 percent. Other covenants include restrictions on the sale of certain assets, limitations on indebtedness and the making of certain investments.
On June 15, 2020, Cascade issued $i50.0 million
of senior notes under a note purchase agreement with maturity dates ranging from June 15, 2050 to June 15, 2060, at a weighted average interest rate of i3.66 percent. The agreement contains customary covenants and provisions, including a covenant of Cascade not to permit, at any time, the ratio of total debt to total capitalization to be greater than i65 percent.
On
October 30, 2020, Cascade issued $i25.0 million of senior notes under a note purchase agreement with a maturity date of October 30, 2060, at an interest rate of i3.34 percent.
The agreement contains customary covenants and provisions, including a covenant of Cascade not to permit, at any time, the ratio of total debt to total capitalization to be greater than i65 percent.
Cascade's ratio of total debt to total capitalization at December 31, 2020, was i53 percent.
Intermountain
Any borrowings under the revolving credit agreement are classified as long-term debt as they are intended to be refinanced on a long-term basis through continued borrowings. The credit agreement contains customary covenants and provisions, including a covenant of Intermountain not to permit, at any time, the ratio of total debt to total capitalization to be greater than i65 percent. Other covenants include restrictions on the sale of certain assets, limitations on indebtedness and the making of certain
investments.
Intermountain's ratio of total debt to total capitalization at December 31, 2020, was i51 percent.
Centennial Centennial's revolving credit agreement supports its commercial paper program. Commercial paper borrowings under this agreement are classified as long-term debt as they are intended to be refinanced on a long-term basis through continued commercial paper borrowings. Centennial's revolving credit agreement contains
customary covenants and provisions, including a covenant of Centennial, not to permit, as of the end of any fiscal quarter, the ratio of total consolidated debt to total consolidated capitalization to be greater than i65 percent. Other covenants include restricted payments, restrictions on the sale of certain assets, limitations on subsidiary indebtedness, minimum consolidated net worth, limitations on priority debt and the making of certain loans and investments.
Centennial's ratio
of total debt to total capitalization at December 31, 2020, was i31 percent.
Certain of Centennial's financing agreements contain cross-default provisions. These provisions state that if Centennial or any subsidiary of Centennial fails to make any payment with respect to any indebtedness or contingent obligation, in excess of a specified amount, under any agreement that causes such indebtedness to be due prior to its stated maturity or the contingent obligation to become payable, the applicable agreements
will be in default.
WBI Energy Transmission On July 26, 2019, WBI Energy Transmission amended its uncommitted note purchase and private shelf agreement to increase capacity to $i300.0 million and extend the issuance period to May 16, 2022. On December 16, 2020, WBI Energy Transmission issued $i25.0 million
of senior notes under the private shelf agreement with a maturity date of December 16, 2035, at an interest rate of i3.26 percent. WBI Energy Transmission had $i195.0 million
of notes outstanding at December 31, 2020, which reduced the remaining capacity under this uncommitted private shelf agreement to $i105.0 million. This agreement contains customary covenants and provisions, including a covenant of WBI Energy Transmission not to permit, as of the end of any fiscal quarter, the ratio of total debt to total capitalization to be greater than i55 percent.
Other covenants include a limitation on priority debt and restrictions on the sale of certain assets and the making of certain investments.
WBI Energy Transmission's ratio of total debt to total capitalization at December 31, 2020, was i41 percent.
Schedule of Debt Maturities iLong-term
debt maturities, which excludes unamortized debt issuance costs and discount, for the five years and thereafter following December 31, 2020, were as follows:
2021
2022
2023
2024
2025
Thereafter
(In
thousands)
Long-term debt maturities
$
i1,555
$
i148,021
$
i77,921
$
i282,922
$
i177,802
$
i1,530,713
82 MDU
Resources Group, Inc. Form 10-K
Part II
Note 10 - iLeases
Most of the leases the Company enters into are for equipment, buildings, easements and vehicles as part of their ongoing operations. The Company also leases certain equipment to third parties through its utility and construction services segments. The Company determines if an arrangement contains a lease at inception of a contract and accounts for all leases in accordance with ASC 842 - Leases.
The recognition of leases requires the Company to make
estimates and assumptions that affect the lease classification and the assets and liabilities recorded. The accuracy of lease assets and liabilities reported on the Consolidated Financial Statements depends on, among other things, management's estimates of interest rates used to discount the lease assets and liabilities to their present value, as well as the lease terms based on the unique facts and circumstances of each lease.
Lessee accounting
The leases the Company has entered into as part of its ongoing operations are considered operating leases and are recognized on the Consolidated Balance Sheets as operating lease right-of-use assets, operating lease liabilities due within one year and, if applicable, noncurrent liabilities - operating lease liabilities. The corresponding lease costs are included in operation
and maintenance expense on the Consolidated Statements of Income.
Generally, the leases for vehicles and equipment have a term of five years or less and buildings and easements have a longer term of up to 35 years or more. To date, the Company does not have any residual value guarantee amounts probable of being owed to a lessor, financing leases or material agreements with related parties.
i
The following tables provide information on the
Company's operating leases at and for the years ended December 31:
2020
2019
(In thousands)
Lease costs:
Operating lease cost
$
i45,319
$
i43,759
Variable
lease cost
i1,319
i1,555
Short-term
lease cost
i135,376
i120,030
Total
lease costs
$
i182,014
$
i165,344
2020
2019
(Dollars
in thousands)
Weighted average remaining lease term
i2.73 years
i3.13
years
Weighted average discount rate
i4.03
%
i4.41
%
Cash
paid for amounts included in the measurement of lease liabilities
$
i45,043
$
i43,477
/i
The
reconciliation of the future undiscounted cash flows to the operating lease liabilities presented on the Consolidated Balance Sheet at December 31, 2020, was as follows:
(In thousands)
2021
$
i36,632
2022
i25,133
2023
i16,639
2024
i12,140
2025
i7,852
Thereafter
i48,845
Total
i147,241
Less
discount
i26,718
Total operating lease liabilities
$
i120,523
/i
Lessor
accounting
The Company leases certain equipment to third parties through its utility and construction services segments, which are considered short-term operating leases with terms of less than 12 months. The Company recognized revenue from operating leases of $i48.0 million and $i51.5
million for the years ended December 31, 2020 and 2019, respectively. At December 31, 2020, the Company had $i11.2 million of lease receivables with a majority due within 12 months or less.
/
MDU
Resources Group, Inc. Form 10-K 83
Part II
Note 11 - iAsset
Retirement Obligations
The Company records obligations related to retirement costs of natural gas distribution mains and lines, natural gas transmission lines, natural gas storage wells, decommissioning of certain electric generating facilities, reclamation of certain aggregate properties, special handling and disposal of hazardous materials at certain electric generating facilities, natural gas distribution facilities and buildings, and certain other obligations as asset retirement obligations.
i
A
reconciliation of the Company's liability, which the current portion is included in other accrued liabilities on the Consolidated Balance Sheets, for the years ended December 31 was as follows:
2020
2019
(In thousands)
Balance at beginning of year
$
i417,575
$
i375,553
Liabilities
incurred
i11,560
i25,869
Liabilities
acquired
i1,378
i486
Liabilities
settled
(i5,369)
(i7,097)
Accretion
expense*
i21,668
i19,789
Revisions
in estimates
i107
i2,975
Balance
at end of year
$
i446,919
$
i417,575
* Includes
$i20.1 million and $i18.3 million in 2020 and
2019, respectively, related to regulatory assets.
/
The Company believes that largely all expenses related to asset retirement obligations at the Company's regulated operations will be recovered in rates over time and, accordingly, defers such expenses as regulatory assets. For more information on the Company's regulatory assets and liabilities, see Note 6.
Note 12
- iEquity
The Company depends on earnings and dividends from its subsidiaries to pay dividends on common stock. The Company has paid quarterly dividends for 83 consecutive years with an increase in the dividend amount for the last 30 consecutive years. For the years ended
December 31, 2020, 2019 and 2018, dividends declared on common stock were $i.8350, $i.8150
and $i.7950 per common share, respectively. Dividends on common stock are paid quarterly to the stockholders of record less than 30 days prior to the distribution date. For the years ended December 31, 2020, 2019 and 2018, the dividends declared to common stockholders were $i167.4 million,
$i162.1 million and $i155.7 million, respectively.
The declaration and payment of dividends of the
Company is at the sole discretion of the board of directors. In addition, the Company's subsidiaries are generally restricted to paying dividends out of capital accounts or net assets. The following discusses the most restrictive limitations.
Pursuant to a covenant under a credit agreement, Centennial may only declare or pay distributions if, as of the last day of any fiscal quarter, the ratio of Centennial's average consolidated indebtedness as of the last day of such fiscal quarter and each of the preceding three fiscal quarters to Centennial's Consolidated EBITDA does not exceed i3.5
to 1. In addition, certain credit agreements and regulatory limitations of the Company's subsidiaries also contain restrictions on dividend payments. The most restrictive limitation requires the Company's subsidiaries not to permit the ratio of funded debt to capitalization to be greater than i65 percent.
Based on this limitation, approximately $i1.4 billion of the net assets of the Company's subsidiaries, which represents common stockholders' equity including retained earnings, would be restricted from use for dividend payments at December 31, 2020.
The Company currently has a shelf registration statement on file with the SEC, under which the Company may issue and sell any combination of common stock and debt securities. The Company may sell such securities if warranted by market conditions and the Company's capital requirements. Any public offer and sale of such securities will be made only by means of a prospectus meeting the requirements of the Securities Act and the rules and regulations thereunder.
In August 2020, the
Company amended the Distribution Agreement dated February 22, 2019, with J.P. Morgan Securities LLC and MUFG Securities Americas Inc., as sales agents. The Distribution Agreement allows the offering, issuance and sale of up to i6.4 million shares of the Company's common stock in connection with an “at-the-market” offering. The common stock may be offered for sale, from time to time, in accordance with the terms and conditions
of the agreement.
The Company did inot issue shares of common stock for the year ended December 31, 2020, pursuant to the “at-the-market” offering. The Company issued i3.6 million
shares of common stock for the year ended December 31, 2019, pursuant to the "at-the-market" offering. For the year ended December 31, 2019, the Company received net proceeds of $i94.0 million and paid commissions to the sales agents of approximately $i950,000
in connection with the sales of common stock under the "at-the-market" offering. The net proceeds were used for capital expenditures and acquisitions. As of December 31, 2020, the Company had capacity to issue up to i6.4 million additional shares of common stock under the "at-the-market" offering program.
84 MDU
Resources Group, Inc. Form 10-K
Part II
The K-Plan provides participants the option to invest in the Company's common stock. For the years ended December 31, 2020, 2019 and 2018, the K-Plan purchased shares of common stock on the open market or issued original issue common stock of the
Company. At December 31, 2020, there were i7.2 million shares of common stock reserved for original issuance under the K-Plan.
The Company currently has i2.0 million
shares of preferred stock authorized to be issued with a $i100 par value. At December 31, 2020 and 2019, there were iino/
shares outstanding.
Note 13 - iStock-Based Compensation
The Company has stock-based compensation plans under which it is currently authorized to grant restricted stock and other stock awards. As of December 31,
2020, there were i4.2 million remaining shares available to grant under these plans. The Company either purchases shares on the open market or issues new shares of common stock to satisfy the vesting of stock-based awards.
Total stock-based compensation expense (after tax) was $i10.8 million,
$i6.5 million and $i4.6 million in 2020, 2019 and 2018, respectively.
As
of December 31, 2020, total remaining unrecognized compensation expense related to stock-based compensation was approximately $i10.9 million (before income taxes) which will be amortized over a weighted average period of i1.6 years.
Stock
awards
Non-employee directors receive shares of common stock in addition to and in lieu of cash payment for directors' fees. There were i45,273 shares with a fair value of $i1.1 million,
i41,644 shares with a fair value of $i1.2 million
and i38,605 shares with a fair value of $i1.0 million
issued to non-employee directors during the years ended December 31, 2020, 2019 and 2018, respectively.
Restricted stock awards
In February 2018, the Company granted restricted stock awards under the long-term performance-based incentive plan to certain key employees. The Company granted i22,838
shares at a weighted average grant-date fair value of $i27.48 per share. The restricted stock awards vested on December 31, 2020. The fair value of the vested awards was $i600,000.
Performance
share awards
Since 2003, key employees of the Company have been granted performance share awards each year under the long-term performance-based incentive plan. Entitlement to performance shares is established by either the market condition or the performance metrics and service condition relative to the designated award.
i
Target grants of performance shares outstanding at December 31, 2020, were as follows:
Grant
Date
Performance Period
Target Grant of Shares
February 2019
2019-2021
i327,194
February
2020
2020-2022
i285,980
/
Under the market condition for these performance share awards, participants may earn from
izero to i200 percent of the apportioned target grant of shares based on the
Company's total shareholder return relative to that of the selected peer group. Compensation expense is based on the grant-date fair value as determined by Monte Carlo simulation. The blended volatility term structure ranges are comprised of i50 percent historical volatility and i50 percent
implied volatility. Risk-free interest rates were based on U.S. Treasury security rates in effect as of the grant date. iAssumptions used for grants applicable to the market condition for certain performance shares issued in 2020, 2019 and 2018 were:
2020
2019
2018
Weighted
average grant-date fair value
$i40.75
$i35.07
$i34.55
Blended
volatility range
i15.30
%
–
i15.97
%
i19.50
%
–
i19.69
%
i17.87
%
–
i22.14
%
Risk-free
interest rate range
i1.45
%
–
i1.62
%
i2.46
%
–
i2.55
%
i1.86
%
–
i2.46
%
Weighted
average discounted dividends per share
$i2.91
$i2.85
$i2.46
Under
the performance conditions for these performance share awards, participants may earn from izero to i200 percent
of the apportioned target grant of shares. The performance conditions are based on the Company's compound annual growth rate in earnings from continuing operations before interest, taxes, depreciation, depletion and amortization and the Company's compound annual growth rate in earnings from continuing operations. The weighted average grant-date fair value per share for the performance shares applicable to these performance conditions issued in 2020, 2019 and 2018 was $i31.63,
$i26.25 and $i27.48,
respectively.
The fair value of the performance shares that vested during both years ended December 31, 2020 and 2019, was $ii9.7/
million. There were ino performance shares that vested in 2018.
MDU Resources Group, Inc. Form
10-K 85
Part II
i
A summary of the status of the performance share awards for the year ended December 31, 2020, was as follows:
Number
of Shares
Weighted Average Grant-Date Fair Value
Nonvested at beginning of period
i573,503
$
i30.81
Granted
i285,980
i36.19
Additional
performance shares earned
i123,147
i27.48
Less:
Vested
i369,456
i29.84
Nonvested
at end of period
i613,174
$
i33.24
/
Note
14 - iAccumulated Other Comprehensive Income (Loss)
iThe Company's accumulated other comprehensive income
(loss) is comprised of losses on derivative instruments qualifying as hedges, postretirement liability adjustments and gain (loss) on available-for-sale investments.
i
The after-tax changes in the components of accumulated other comprehensive loss at December 31, 2020, 2019 and 2018, were as follows:
Net Unrealized Loss
on Derivative Instruments Qualifying as Hedges
Post- retirement Liability Adjustment
Net Unrealized Gain (Loss) on Available- for-sale Investments
The
following amounts were reclassified out of accumulated other comprehensive loss into net income. The amounts presented in parenthesis indicate a decrease to net income on the Consolidated Statements of Income. The reclassifications for the years ended December 31 were as follows:
2020
2019
Location on Consolidated Statements of Income
(In thousands)
Reclassification
adjustment for loss on derivative instruments included in net income
$
(i591)
$
(i591)
Interest
expense
i145
(i140)
Income
taxes
(i446)
(i731)
Amortization
of postretirement liability losses included in net periodic benefit cost
(i2,552)
(i1,962)
Other
income
i630
i476
Income
taxes
(i1,922)
(i1,486)
Reclassification
adjustment for loss on available-for-sale investments included in net income
(i66)
(i50)
Other
income
i14
i10
Income
taxes
(i52)
(i40)
Total
reclassifications
$
(i2,420)
$
(i2,257)
/
86 MDU
Resources Group, Inc. Form 10-K
Part II
Note 15 - iIncome Taxes
i
The
components of income before income taxes from continuing operations for each of the years ended December 31 were as follows:
2020
2019
2018
(In thousands)
United States
$
i474,856
$
i398,532
$
i317,655
Foreign
i261
(i87)
(i784)
Income
before income taxes from continuing operations
$
i475,117
$
i398,445
$
i316,871
/i
Income
tax expense (benefit) from continuing operations for the years ended December 31 was as follows:
2020
2019
2018
(In thousands)
Current:
Federal
$
i65,006
$
(i3,502)
$
(i15,901)
State
i21,234
i3,366
i3,651
Foreign
i151
i—
i—
i86,391
(i136)
(i12,250)
Deferred:
Income
taxes:
Federal
(i3,735)
i50,218
i50,755
State
(i625)
i12,098
i7,206
Investment
tax credit - net
i2,559
i1,099
i1,774
(i1,801)
i63,415
i59,735
Total
income tax expense
$
i84,590
$
i63,279
$
i47,485
/
The
TCJA was enacted on December 22, 2017. The SEC issued rules that allowed for a measurement period of up to 12 months after the enactment date of the TCJA to finalize the recording of the related tax impacts. The Company reviewed the impacts of the TCJA and completed its assessment of the transitional impacts during the period ending December 31, 2018, of which there were no such material adjustments.
i
Components
of deferred tax assets and deferred tax liabilities at December 31 were as follows:
2020
2019
(In thousands)
Deferred tax assets:
Postretirement
$
i51,495
$
i51,075
Compensation-related
i40,477
i37,330
Operating
lease liabilities
i25,963
i24,459
Payroll
tax deferral
i14,010
i—
Legal
and environmental contingencies
i9,467
i6,601
Asset
retirement obligations
i8,060
i7,450
Customer
advances
i7,463
i7,325
Federal
renewable energy credit
i—
i5,343
Other
i37,944
i32,533
Total
deferred tax assets
i194,879
i172,116
Deferred
tax liabilities:
Depreciation and basis differences on property, plant and equipment
i536,966
i511,867
Postretirement
i49,233
i48,927
Operating
lease right-of-use-assets
i25,858
i24,436
Intangible
asset amortization
i19,514
i18,930
Other
i67,922
i61,385
Total
deferred tax liabilities
i699,493
i665,545
Valuation
allowance
i11,484
i13,154
Net
deferred income tax liability
$
i516,098
$
i506,583
/
As
of December 31, 2020 and 2019, the Company had various state income tax net operating loss carryforwards of $i151.5 million and $i149.8 million,
respectively, and federal and state income tax credit carryforwards, excluding alternative minimum tax credit carryforwards, of $i37.1 million and $i43.7 million, respectively.
Included in the state credits are various regulatory investment tax credits of approximately $i36.3 million and $i37.4 million at December 31,
2020 and 2019, respectively. The state income tax credit carryforwards are due to expire between
MDU Resources Group, Inc. Form 10-K 87
Part II
2021 and 2034. Changes in tax regulations or assumptions regarding current and future taxable income could require additional valuation allowances in
the future.
i
The following table reconciles the change in the net deferred income tax liability from December 31, 2019, to December 31, 2020, to deferred income tax benefit:
2020
(In
thousands)
Change in net deferred income tax liability from the preceding table
$
i9,515
Deferred taxes associated with other comprehensive loss
i1,817
Excess
deferred income tax amortization
(i12,517)
Other
(i616)
Deferred
income tax benefit for the period
$
(i1,801)
/i
Total
income tax expense differs from the amount computed by applying the statutory federal income tax rate to income before taxes. The reasons for this difference were as follows:
TCJA
revaluation related to accumulated other comprehensive loss balance
i—
i—
i—
i—
(i42)
i—
Other
(i961)
(i.3)
(i3,938)
(i.9)
(i1,456)
(i.4)
Total
income tax expense
$
i84,590
i17.8
$
i63,279
i15.9
$
i47,485
i15.0
/
The
Company and its subsidiaries file income tax returns in the U.S. federal jurisdiction, and various state, local and foreign jurisdictions. The Company is no longer subject to U.S. federal or non-U.S. income tax examinations by tax authorities for years ending prior to 2016. With few exceptions, as of December 31, 2020, the Company is no longer subject to state and local income tax examinations by tax authorities for years ending prior to 2016.
For the years ended December 31, 2020, 2019 and 2018,
total reserves for uncertain tax positions were not material. The Company recognizes interest and penalties accrued relative to unrecognized tax benefits in income tax expense.
Note 16 - iCash Flow Information
i
Cash
expenditures for interest and income taxes for the years ended December 31 were as follows:
2020
2019
2018
(In thousands)
Interest, net*
$
i88,681
$
i93,414
$
i83,009
Income
taxes paid (refunded), net**
$
i65,536
$
(i8,475)
$
i16,041
* AFUDC
- borrowed was $i2.6 million, $i2.8 million and $i2.3 million
for the years ended December 31, 2020, 2019 and 2018, respectively.
** Income taxes paid (refunded), including discontinued operations, were $i59.4 million, $(i9.4) million
and $i5.5 million for the years ended December 31, 2020, 2019 and 2018, respectively.
Noncash investing and financing transactions at December 31 were as follows:
2020
2019
2018
(In
thousands)
Property, plant and equipment additions in accounts payable
$
i26,082
$
i46,119
$
i42,355
Right-of-use
assets obtained in exchange for new operating lease liabilities
$
i54,356
$
i54,880
$
i—
Issuance
of common stock in connection with acquisition
$
i—
$
i—
$
i18,186
Debt
assumed in connection with a business combination
$
i—
$
i1,163
$
i—
Accrual
for holdback payment related to a business combination
$
i2,500
$
i—
$
i—
/
88 MDU
Resources Group, Inc. Form 10-K
Part II
Note 17 - iBusiness
Segment Data
iThe Company's reportable segments are those that are based on the Company's method of internal reporting, which generally segregates the strategic business units due to differences in products, services and regulation. The internal reporting of these operating segments is defined based on the reporting and review process used by the
Company's chief executive officer.The Company's operations are located within the United States.
The electric segment generates, transmits and distributes electricity in Montana, North Dakota, South Dakota and Wyoming. The natural gas distribution segment distributes natural gas in those states, as well as in Idaho, Minnesota, Oregon and Washington. These operations also supply related value-added services.
The pipeline segment provides natural gas transportation and underground storage services through a regulated pipeline system primarily in the Rocky Mountain and northern Great Plains regions of the United States. This segment also provides non-regulated cathodic protection and other energy-related services. In 2020, the pipeline segment divested its regulated and non-regulated natural
gas gathering assets. With the completion of these sales, the segment has exited the natural gas gathering business.
The construction materials and contracting segment mines, processes and sells construction aggregates (crushed stone, sand and gravel); produces and sells asphalt mix; and supplies ready-mixed concrete. This segment focuses on vertical integration of its contracting services with its construction materials to support the aggregate-based product lines including aggregate placement, asphalt and concrete paving, and site development and grading. Although not common to all locations, other products include the sale of cement, liquid asphalt for various commercial and roadway applications, various finished concrete products and other building materials and related contracting services. This segment operates in the central, southern and western United States, including Alaska and Hawaii.
The
construction services segment provides inside and outside specialty contracting services in 44 states plus Washington D.C. Its inside services include design, construction and maintenance of electrical and communication wiring and infrastructure, fire suppression systems, and mechanical piping and services. Its outside services include design, construction and maintenance of overhead and underground electrical distribution and transmission lines, substations, external lighting, traffic signalization, and gas pipelines, as well as utility excavation and the manufacture and distribution of transmission line construction equipment. This segment also constructs and maintains renewable energy projects. These specialty contracting services are provided to utilities and large manufacturing, commercial, industrial, institutional and governmental customers.
The Other category includes the activities of Centennial Capital, which, through
its subsidiary InterSource Insurance Company, insures various types of risks as a captive insurer for certain of the Company's subsidiaries. The function of the captive insurer is to fund the self-insured layers of the insured Company's general liability, automobile liability, pollution liability and other coverages. Centennial Capital also owns certain real and personal property. In addition, the Other category includes certain assets, liabilities and tax adjustments of the holding company primarily associated with corporate functions and certain general and administrative costs (reflected in operation and maintenance expense) and interest expense, which were previously allocated to the refining business and Fidelity and do not meet the criteria for income (loss) from discontinued operations. The
Other category also includes Centennial Resources' former investment in Brazil.
Discontinued operations include the results and supporting activities of Dakota Prairie Refining and Fidelity other than certain general and administrative costs and interest expense as described above.
The information below follows the same accounting policies as described in Note 2. iInformation on the
Company's segments as of December 31 and for the years then ended was as follows:
2020
2019
2018
(In thousands)
External operating revenues:
Regulated
operations:
Electric
$
i331,538
$
i351,725
$
i335,123
Natural
gas distribution
i847,651
i865,222
i823,247
Pipeline
i69,957
i62,357
i54,857
i1,249,146
i1,279,304
i1,213,227
Non-regulated
operations:
Pipeline
i15,389
i21,835
i23,161
Construction
materials and contracting
i2,177,585
i2,189,651
i1,925,185
Construction
services
i2,090,685
i1,845,896
i1,369,772
Other
(i55)
i90
i207
i4,283,604
i4,057,472
i3,318,325
Total
external operating revenues
$
i5,532,750
$
i5,336,776
$
i4,531,552
MDU
Resources Group, Inc. Form 10-K 89
Part II
2020
2019
2018
(In
thousands)
Intersegment operating revenues:
Regulated operations:
Electric
$
i491
$
i—
$
i—
Natural
gas distribution
i534
i—
i—
Pipeline
i57,977
i56,037
i50,580
i59,002
i56,037
i50,580
Non-regulated
operations:
Pipeline
i554
i215
i325
Construction
materials and contracting
i417
i1,066
i669
Construction
services
i5,038
i3,370
i1,681
Other
i11,958
i16,461
i11,052
i17,967
i21,112
i13,727
Intersegment
eliminations
(i76,969)
(i77,149)
(i64,307)
Total
intersegment operating revenues
$
i—
$
i—
$
i—
Depreciation,
depletion and amortization:
Electric
$
i62,998
$
i58,721
$
i50,982
Natural
gas distribution
i84,580
i79,564
i72,486
Pipeline
i21,669
i21,220
i17,896
Construction
materials and contracting
i89,626
i77,450
i61,158
Construction
services
i23,523
i17,038
i15,728
Other
i2,704
i2,024
i1,955
Total
depreciation, depletion and amortization
$
i285,100
$
i256,017
$
i220,205
Operating
income (loss):
Electric
$
i63,434
$
i64,039
$
i65,148
Natural
gas distribution
i73,082
i69,188
i72,336
Pipeline
i49,436
i42,796
i36,128
Construction
materials and contracting
i214,498
i179,955
i141,426
Construction
services
i147,644
i126,426
i86,764
Other
(i3,169)
(i1,184)
(i79)
Total
operating income
$
i544,925
$
i481,220
$
i401,723
Interest
expense:
Electric
$
i26,699
$
i25,334
$
i25,860
Natural
gas distribution
i36,798
i35,488
i30,768
Pipeline
i7,622
i7,198
i5,964
Construction
materials and contracting
i20,577
i23,792
i17,290
Construction
services
i4,095
i5,331
i3,551
Other
i883
i1,859
i2,762
Intersegment
eliminations
(i155)
(i415)
(i1,581)
Total
interest expense
$
i96,519
$
i98,587
$
i84,614
Income
tax expense (benefit):
Electric
$
(i11,636)
$
(i12,650)
$
(i6,482)
Natural
gas distribution
i5,746
i1,405
i4,075
Pipeline
i7,650
i7,219
i2,677
Construction
materials and contracting
i47,431
i37,389
i28,357
Construction
services
i35,797
i29,973
i20,000
Other
(i398)
(i57)
(i1,142)
Total
income expense
$
i84,590
$
i63,279
$
i47,485
90 MDU
Resources Group, Inc. Form 10-K
Part II
2020
2019
2018
(In
thousands)
Net income (loss):
Regulated operations:
Electric
$
i55,601
$
i54,763
$
i47,000
Natural
gas distribution
i44,049
i39,517
i37,732
Pipeline
i35,453
i28,255
i26,905
i135,103
i122,535
i111,637
Non-regulated
operations:
Pipeline
i1,559
i1,348
i1,554
Construction
materials and contracting
i147,325
i120,371
i92,647
Construction
services
i109,721
i92,998
i64,309
Other
(i3,181)
(i2,086)
(i761)
i255,424
i212,631
i157,749
Income
from continuing operations
i390,527
i335,166
i269,386
Income
(loss) from discontinued operations, net of tax
(i322)
i287
i2,932
Net
income
$
i390,205
$
i335,453
$
i272,318
Capital
expenditures:
Electric
$
i114,676
$
i99,449
$
i186,105
Natural
gas distribution
i193,048
i206,799
i205,896
Pipeline
i62,224
i71,477
i70,057
Construction
materials and contracting
i191,635
i190,092
i280,396
Construction
services
i83,651
i60,500
i25,081
Other
i3,045
i8,181
i1,768
Total
capital expenditures (a)
$
i648,279
$
i636,498
$
i769,303
Assets:
Electric
(b)
$
i2,123,693
$
i1,680,194
$
i1,613,822
Natural
gas distribution (b)
i2,302,770
i2,574,965
i2,375,871
Pipeline
i703,377
i677,482
i616,959
Construction
materials and contracting
i1,798,493
i1,684,161
i1,508,032
Construction
services
i818,662
i761,127
i604,798
Other
(c)
i305,157
i303,279
i266,111
Assets
held for sale
i1,220
i1,851
i2,517
Total
assets
$
i8,053,372
$
i7,683,059
$
i6,988,110
Property,
plant and equipment:
Electric (b)
$
i2,323,403
$
i2,227,145
$
i2,148,569
Natural
gas distribution (b)
i2,868,853
i2,688,123
i2,499,093
Pipeline
i821,697
i834,215
i764,959
Construction
materials and contracting
i2,028,476
i1,910,562
i1,768,006
Construction
services
i220,796
i213,370
i188,586
Other
i37,545
i35,213
i28,108
Less
accumulated depreciation, depletion and amortization
i3,133,831
i2,991,486
i2,818,644
Net
property, plant and equipment
$
i5,166,939
$
i4,917,142
$
i4,578,677
(a) Capital
expenditures for 2020, 2019 and 2018 include noncash transactions such as the issuance of the Company's equity securities in connection with acquisitions, capital expenditure-related accounts payable, AFUDC and accrual of holdback payments in connection with acquisitions totaling $(i15.7) million, $i4.8 million
and $i33.4 million, respectively.
(b) Includes allocations of common utility property.
(c) Includes assets not directly assignable to a business (i.e. cash and cash equivalents, certain accounts receivable, certain investments and other miscellaneous current and deferred assets).
MDU
Resources Group, Inc. Form 10-K 91
Part II
Note 18 - iEmployee
Benefit Plans
Pension and other postretirement benefit plans
The Company has noncontributory qualified defined benefit pension plans and other postretirement benefit plans for certain eligible employees. The Company uses a measurement date of December 31 for all of its pension and postretirement benefit plans.
Prior to 2013, defined benefit pension plan benefits and accruals for all nonunion and certain union plans were frozen and on June 30, 2015, the remaining union plan was frozen. These employees were eligible to receive additional defined contribution plan benefits. In October 2018, the
Company transferred the liability of certain participants in the defined benefit pension plan, who are currently receiving benefits, to an annuity company. The transfer of the benefit payments for these participants reduced the Company's liability and future premiums.
Effective January 1, 2010, eligibility to receive retiree medical benefits was modified at certain of the Company's businesses. Employees who had attained age 55 with 10 years of continuous service by December 31, 2010, were provided the option to choose between a pre-65 comprehensive medical plan coupled with a Medicare supplement or a specified company funded Retiree Reimbursement Account, regardless
of when they retire. All other eligible employees must meet the new eligibility criteria of age 60 and 10 years of continuous service at the time they retire to be eligible for a specified company funded Retiree Reimbursement Account. Employees hired after December 31, 2009, will not be eligible for retiree medical benefits at certain of the Company's businesses.
In 2012, the Company modified health care coverage for certain retirees. Effective January 1, 2013, post-65 coverage was replaced by a fixed-dollar subsidy for retirees and spouses to be used to purchase individual insurance through an exchange.
i
Changes
in benefit obligation and plan assets and amounts recognized in the Consolidated Balance Sheets at December 31 were as follows:
Pension Benefits
Other Postretirement Benefits
2020
2019
2020
2019
Change
in benefit obligation:
(In thousands)
Benefit obligation at beginning of year
$
i421,166
$
i391,602
$
i83,614
$
i81,201
Service
cost
i—
i—
i1,532
i1,142
Interest
cost
i12,093
i15,225
i2,437
i2,986
Plan
participants' contributions
i—
i—
i752
i1,040
Actuarial
loss
i27,737
i40,219
i2,203
i2,632
Benefits
paid
(i23,636)
(i25,880)
(i4,383)
(i5,387)
Benefit
obligation at end of year
i437,360
i421,166
i86,155
i83,614
Change
in net plan assets:
Fair value of plan assets at beginning of year
i365,264
i307,809
i94,587
i82,516
Actual
return on plan assets
i42,206
i58,409
i10,249
i15,731
Employer
contribution
i—
i24,926
i434
i687
Plan
participants' contributions
i—
i—
i752
i1,040
Benefits
paid
(i23,636)
(i25,880)
(i4,383)
(i5,387)
Fair
value of net plan assets at end of year
i383,834
i365,264
i101,639
i94,587
Funded
status - over (under)
$
(i53,526)
$
(i55,902)
$
i15,484
$
i10,973
Amounts
recognized in the Consolidated Balance Sheets at December 31:
Noncurrent assets - other
$
i—
$
i—
$
i36,769
i30,475
Other
accrued liabilities
i—
i—
i622
i647
Noncurrent
liabilities - other
i53,526
i55,902
i20,663
i18,855
Benefit
obligation assets (liabilities) - net amount recognized
$
(i53,526)
$
(i55,902)
$
i15,484
$
i10,973
Amounts
recognized in accumulated other comprehensive loss:
Actuarial loss
$
i27,527
$
i27,748
$
i5,557
$
i6,118
Prior
service credit
i—
i—
(i634)
(i731)
Total
$
i27,527
$
i27,748
$
i4,923
$
i5,387
Amounts
recognized in regulatory assets or liabilities:
Actuarial (gain) loss
$
i154,013
$
i155,484
$
(i8,228)
$
(i4,450)
Prior
service credit
i—
i—
(i6,808)
(i8,109)
Total
$
i154,013
$
i155,484
$
(i15,036)
$
(i12,559)
/
Employer
contributions and benefits paid in the preceding table include only those amounts contributed directly to, or paid directly from, plan assets. Amounts related to regulated operations are recorded as regulatory assets or liabilities and are expected to be reflected in rates charged to customers over time. For more information on regulatory assets and liabilities, see Note 6.
92 MDU Resources Group, Inc. Form 10-K
Part II
Unrecognized
pension actuarial losses in excess of 10 percent of the greater of the projected benefit obligation or the market-related value of assets are amortized over the average life expectancy of plan participants for frozen plans. The market-related value of assets is determined using a five-year average of assets.
i
The pension plans all have accumulated benefit obligations in excess of plan assets. The projected benefit obligation, accumulated benefit obligation and fair
value of plan assets for these plans at December 31 were as follows:
2020
2019
(In thousands)
Projected benefit obligation
$
i437,360
$
i421,166
Accumulated
benefit obligation
$
i437,360
$
i421,166
Fair
value of plan assets
$
i383,834
$
i365,264
/i
The
components of net periodic benefit cost (credit), other than the service cost component, are included in other income on the Consolidated Statements of Income. These components related to the Company's pension and other postretirement benefit plans for the years ended December 31 were as follows:
Pension Benefits
Other Postretirement
Benefits
2020
2019
2018
2020
2019
2018
Components of net periodic benefit cost (credit):
(In thousands)
Service cost
$
i—
$
i—
$
i—
$
i1,532
$
i1,142
$
i1,494
Interest
cost
i12,093
i15,225
i14,591
i2,437
i2,986
i2,899
Expected
return on assets
(i19,949)
(i18,236)
(i20,753)
(i5,019)
(i4,804)
(i4,866)
Amortization
of prior service credit
i—
i—
i—
(i1,398)
(i1,398)
(i1,394)
Recognized
net actuarial loss
i7,172
i5,548
i7,005
i287
i353
i640
Net
periodic benefit cost (credit), including amount capitalized
(i684)
i2,537
i843
(i2,161)
(i1,721)
(i1,227)
Less
amount capitalized
i—
i—
i—
i156
i113
i153
Net
periodic benefit cost (credit)
(i684)
i2,537
i843
(i2,317)
(i1,834)
(i1,380)
Other
changes in plan assets and benefit obligations recognized in accumulated comprehensive loss:
Net (gain) loss
i934
(i144)
i991
(i259)
(i127)
(i1,735)
Amortization
of actuarial loss
(i1,155)
(i904)
(i1,084)
(i306)
(i110)
(i354)
Amortization
of prior service (cost) credit
i—
i—
i—
i101
i100
(i220)
Total
recognized in accumulated other comprehensive loss
(i221)
(i1,048)
(i93)
(i464)
(i137)
(i2,309)
Other
changes in plan assets and benefit obligations recognized in regulatory assets or liabilities:
Net (gain) loss
i4,546
i189
i8,263
(i3,793)
(i8,168)
(i732)
Amortization
of actuarial gain (loss)
(i6,017)
(i4,644)
(i5,921)
i19
(i242)
(i286)
Amortization
of prior service credit
i—
i—
i—
i1,297
i1,297
i1,614
Total
recognized in regulatory assets or liabilities
(i1,471)
(i4,455)
i2,342
(i2,477)
(i7,113)
i596
Total
recognized in net periodic benefit cost (credit), accumulated other comprehensive loss and regulatory assets or liabilities
$
(i2,376)
$
(i2,966)
$
i3,092
$
(i5,258)
$
(i9,084)
$
(i3,093)
/
The
estimated net loss for the defined benefit pension plans that will be amortized from accumulated other comprehensive loss and regulatory assets or liabilities into net periodic benefit cost in 2021 is $i8.0 million. The estimated net loss and prior service credit for the other postretirement benefit plans that will be amortized from accumulated other comprehensive loss and regulatory assets or liabilities into net periodic benefit credit in 2021 are $i24,000
and $i1.4 million, respectively. Prior service credit is amortized on a straight-line basis over the average remaining service period of active participants.
MDU Resources Group, Inc.
Form 10-K 93
Part II
i
Weighted average assumptions used to determine benefit obligations at December 31 were as follows:
Pension
Benefits
Other Postretirement Benefits
2020
2019
2020
2019
Discount rate
i2.30
%
i2.96
%
i2.30
%
i3.00
%
Expected
return on plan assets
i6.00
%
i6.25
%
i5.50
%
i5.75
%
Rate
of compensation increase
N/A
N/A
i3.00
%
i3.00
%
Weighted
average assumptions used to determine net periodic benefit cost (credit) for the years ended December 31 were as follows:
Pension Benefits
Other Postretirement Benefits
2020
2019
2020
2019
Discount
rate
i2.96
%
i4.03
%
i3.00
%
i4.05
%
Expected
return on plan assets
i6.25
%
i6.25
%
i5.75
%
i5.75
%
Rate
of compensation increase
N/A
N/A
i3.00
%
i3.00
%
/
The
expected rate of return on pension plan assets is based on a targeted asset allocation range determined by the funded ratio of the plan. As of December 31, 2020, the expected rate of return on pension plan assets is based on the targeted asset allocation range of i35 percent to i45 percent
equity securities and i55 percent to i65 percent fixed-income securities and the expected rate of return from these
asset categories. The expected rate of return on other postretirement plan assets is based on the targeted asset allocation range of i10 percent equity securities and i90 percent
fixed-income securities and the expected rate of return from these asset categories. The expected return on plan assets for other postretirement benefits reflects insurance-related investment costs.
i
Health care rate assumptions for the Company's other postretirement benefit plans as of December 31 were as follows:
2020
2019
Health
care trend rate assumed for next year
i7.0
%
i7.1
%
–
i7.4
%
Health
care cost trend rate - ultimate
i4.5
%
i4.5
%
Year
in which ultimate trend rate achieved
i2031
i2024
/
The
Company's other postretirement benefit plans include health care and life insurance benefits for certain retirees. The plans underlying these benefits may require contributions by the retiree depending on such retiree's age and years of service at retirement or the date of retirement. The Company contributes a flat dollar amount to the monthly premiums which is updated annually on January 1.
i
Assumed
health care cost trend rates may have a significant effect on the amounts reported for the health care plans. A one percentage point change in the assumed health care cost trend rates would have had the following effects at December 31, 2020:
1 Percentage Point Increase
1 Percentage Point Decrease
(In thousands)
Effect on total of service
and interest cost components
$
i182
$
(i154)
Effect
on postretirement benefit obligation
$
i3,846
$
(i3,304)
/
The
Company does inot expect to contribute to its defined benefit pension plans in 2021 due to an additional $ii20.0/ million
contributed to the plans in 2019. The Company expects to contribute approximately $i500,000 to its postretirement benefit plans in 2021.
i
The
following benefit payments, which reflect future service, as appropriate, and expected Medicare Part D subsidies at December 31, 2020, are as follows:
Years
Pension Benefits
Other Postretirement Benefits
Expected Medicare Part D Subsidy
(In thousands)
2021
$
i24,455
$
i5,404
$
i95
2022
i24,507
i5,437
i89
2023
i24,733
i5,424
i83
2024
i24,835
i5,377
i75
2025
i24,713
i5,277
i70
2026-2030
i119,191
i25,949
i252
/
94 MDU
Resources Group, Inc. Form 10-K
Part II
Outside investment managers manage the Company's pension and postretirement assets. The Company's investment policy with respect to pension and other postretirement assets is to make investments solely in the interest of the participants and beneficiaries of the plans and for the exclusive purpose of providing benefits accrued and defraying the reasonable expenses
of administration. The Company strives to maintain investment diversification to assist in minimizing the risk of large losses. The Company's policy guidelines allow for investment of funds in cash equivalents, fixed-income securities and equity securities. The guidelines prohibit investment in commodities and futures contracts, equity private placement, employer securities, leveraged or derivative securities, options, direct real estate investments, precious metals, venture capital and limited partnerships. The guidelines also prohibit short selling and margin transactions. The Company's practice is to periodically review and rebalance
asset categories based on its targeted asset allocation percentage policy.
Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability (an exit price) in an orderly transaction between market participants at the measurement date. The fair value ASC establishes a hierarchy for grouping assets and liabilities, based on the significance of inputs. The estimated fair values of the Company's pension plans' assets are determined using the market approach.
The carrying value of the pension plans' Level 2 cash equivalents approximates fair value and is determined using observable inputs in active markets or the net asset value of shares held at year end, which is determined using other observable inputs including pricing from outside sources.
The
estimated fair value of the pension plans' Level 1 and Level 2 equity securities are based on the closing price reported on the active market on which the individual securities are traded or other known sources including pricing from outside sources. The estimated fair value of the pension plans' Level 1 and Level 2 collective and mutual funds are based on the net asset value of shares held at year end, based on either published market quotations on active markets or other known sources including pricing from outside sources. The estimated fair value of the pension plans' Level 2 corporate and municipal bonds is determined using other observable inputs, including benchmark yields, reported trades, broker/dealer quotes, bids, offers, future cash flows and other reference data. The estimated fair value of the pension plans' Level 1 U.S. Government securities are valued based on quoted prices on an active market. The estimated fair value of the pension
plans' Level 2 U.S. Government securities are valued mainly using other observable inputs, including benchmark yields, reported trades, broker/dealer quotes, bids, offers, to be announced prices, future cash flows and other reference data. Some of these securities are valued using pricing from outside sources.
All investments measured at net asset value in the tables that follow are invested in comingled funds, separate accounts or common collective trusts which do not have publicly quoted prices. The fair value of the comingled funds, separate accounts and common collective trusts are determined based on the net asset value of the underlying investments. The fair value of the underlying investments held by the comingled funds, separate accounts and common collective trusts is generally based on quoted prices in active markets.
Though the
Company believes the methods used to estimate fair value are consistent with those used by other market participants, the use of other methods or assumptions could result in a different estimate of fair value.
i
The fair value of the Company's pension plans' assets (excluding cash) by class were as follows:
*Collective
and mutual funds invest approximately i36 percent in corporate bonds, i24 percent
in common stock of international companies, i18 percent in common stock of large-cap U.S. companies, i8
percent in cash equivalents, i5 percent in U.S. Government securities and i9 percent
in other investments.
*Collective
and mutual funds invest approximately i29 percent in common stock of international companies, i21
percent in common stock of large-cap U.S. companies, i18 percent in U.S. Government securities, i9
percent in corporate bonds, i6 percent in cash equivalents and i17
percent in other investments.
The estimated fair values of the Company's other postretirement benefit plans' assets are determined using the market approach.
The estimated fair value of the other postretirement benefit plans' Level 2 cash equivalents is valued at the net asset value of shares held at year end, based on published market quotations on active markets, or using other known sources including pricing from outside sources. The estimated fair value of the other postretirement benefit plans' Level 1 and Level 2 equity securities is based on the closing price reported on the active market on which the individual securities are traded
or other known sources including pricing from outside sources. The estimated fair value of the other postretirement benefit plans' Level 2 insurance contract is based on contractual cash surrender values that are determined primarily by investments in managed separate accounts of the insurer. These amounts approximate fair value. The managed separate accounts are valued based on other observable inputs or corroborated market data.
Though the Company believes the methods used to estimate fair value are consistent with those used by other market participants, the use of other methods or assumptions could result in a different estimate of fair value.
The fair value of the
Company's other postretirement benefit plans' assets (excluding cash) by asset class were as follows:
(a)Collective
and mutual funds invest approximately i36 percent in corporate bonds, i24 percent in common stock of international companies, i18 percent
in common stock of large-cap U.S. companies, i8 percent in cash equivalents, i5 percent in U.S. Government securities and i9 percent
in other investments.
(b)The insurance contract invests approximately i67 percent in corporate bonds, i12
percent in U.S. Government securities, i10 percent in common stock of large-cap U.S. companies, i4 percent in common stock of small-cap U.S. companies, i1
percent in cash equivalents and i6 percent in other investments.
(a)Collective
and mutual funds invest approximately i29 percent in common stock of international companies, i21 percent in common stock of large-cap U.S. companies, i18
percent in U.S. Government securities, i9 percent in corporate bonds, i6 percent in cash equivalents and i17
percent in other investments.
(b)The insurance contract invests approximately i50 percent in corporate bonds, i25 percent
in common stock of large-cap U.S. companies, i7 percent in U.S. Government securities, i7 percent in common stock of small-cap U.S. companies and i11 percent
in other investments.
Nonqualified benefit plans
In addition to the qualified defined benefit pension plans reflected in the table at the beginning of this note, the Company also has unfunded, nonqualified defined benefit plans for executive officers and certain key management employees that generally provide for defined benefit payments at age 65 following the employee's retirement or, upon death, to their beneficiaries for a 15-year period. In February 2016, the
Company froze the unfunded, nonqualified defined benefit plans to new participants and eliminated benefit increases. Vesting for participants not fully vested was retained.
The projected benefit obligation and accumulated benefit obligation for these plans at December 31 were as follows:
2020
2019
(In thousands)
Projected
benefit obligation
$
i101,242
$
i99,245
Accumulated
benefit obligation
$
i101,242
$
i99,245
The
components of net periodic benefit cost are included in other income on the Consolidated Statements of Income. These components related to the Company's nonqualified defined benefit plans for the years ended December 31 were as follows:
2020
2019
2018
(In
thousands)
Components of net periodic benefit cost:
Service cost
$
i58
$
i109
$
i185
Interest
cost
i2,606
i3,473
i3,157
Recognized
net actuarial loss
i1,192
i764
i1,047
Net
periodic benefit cost
$
i3,856
$
i4,346
$
i4,389
Weighted
average assumptions used at December 31 were as follows:
2020
2019
Benefit obligation discount rate
i1.97
%
i2.73
%
Benefit
obligation rate of compensation increase
N/A
N/A
Net periodic benefit cost discount rate
i2.73
%
i3.86
%
Net
periodic benefit cost rate of compensation increase
N/A
N/A
The amount of future benefit payments for the unfunded, nonqualified defined benefit plans at December 31, 2020, are expected to aggregate as follows:
2021
2022
2023
2024
2025
2026-2030
(In
thousands)
Nonqualified benefits
$
i7,693
$
i6,957
$
i6,933
$
i7,299
$
i7,253
$
i33,938
MDU
Resources Group, Inc. Form 10-K 97
Part II
In 2012, the Company established a nonqualified defined contribution plan for certain key management employees. In 2020, the plan was frozen to new participants and no new Company contributions will be made to the plan after December 31, 2020. A new plan was adopted in 2020 to replace the plan originally established in 2012 with similar provisions. Vesting for participants not fully vested was retained.
Expenses incurred under this plan for 2020, 2019 and 2018 were $i1.8 million, $i1.6 million and $i597,000,
respectively.
The amount of investments that the Company anticipates using to satisfy obligations under these plans at December 31 was as follows:
* For
more information on the insurance contract, see Note 8.
** Investments of life insurance are carried on plan participants (payable upon the employee's death).
Defined contribution plans
The Company sponsors various defined contribution plans for eligible employees and the costs incurred under these plans were $i50.1 million
in 2020, $i51.8 million in 2019 and $i42.4 million in 2018.
98 MDU
Resources Group, Inc. Form 10-K
Part II
Multiemployer plans
The Company contributes to a number of MEPPs under the terms of collective-bargaining agreements that cover its union-represented employees. The risks of participating in these multiemployer plans are different from single-employer plans in the following aspects:
•Assets
contributed to the MEPP by one employer may be used to provide benefits to employees of other participating employers
•If a participating employer stops contributing to the plan, the unfunded obligations of the plan may be borne by the remaining participating employers
•If the Company chooses to stop participating in some of its MEPPs, the Company may be required to pay those plans an amount based on the underfunded status of the plan, referred to as a withdrawal liability
The Company's participation in these plans is outlined in the following table.
Unless otherwise noted, the most recent Pension Protection Act zone status available in 2020 and 2019 is for the plan's year-end at December 31, 2019, and December 31, 2018, respectively. The zone status is based on information that the Company received from the plan and is certified by the plan's actuary. Among other factors, plans in the red zone are generally less than i65 percent funded,
plans in the yellow zone are between i65 percent and i80 percent funded, and plans in the green zone are at least i80 percent
funded.
i
EIN/Pension
Plan Number
Pension Protection Act Zone Status
FIP/RP Status Pending/Implemented
Contributions
Surcharge Imposed
Expiration Date of Collective Bargaining Agreement
Pension Fund
2020
2019
2020
2019
2018
(In
thousands)
Alaska Laborers-Employers Retirement Fund
i91-6028298-i001
iYellow
as of i6/30/2020
iYellow as of i6/30/2019
iImplemented
$
i828
$
i815
$
i732
iNo
i12/31/2020
*
Construction
Industry and Laborers Joint Pension Trust for So Nevada, Plan A
i88-0135695-i001
iRed
iRed
iImplemented
i515
i544
i346
iNo
i6/30/2023
Edison
Pension Plan
i93-6061681-i001
iGreen
iGreen
iNo
i16,121
i12,252
i12,111
iNo
i12/31/2021
IBEW
Local 212 Pension Trust
i31-6127280-i001
iGreen
as of i4/30/2020
iGreen as of i4/30/2019
iNo
i1,521
i1,110
i1,341
iNo
i6/1/2025
IBEW
Local 357 Pension Plan A
i88-6023284-i001
iGreen
iGreen
iNo
i9,913
i10,162
i3,460
iNo
i5/31/2021
IBEW
Local 38 Pension Plan
i34-6574238-i001
iRed
as of i4/30/2020
iYellow as of i4/30/2019
iImplemented
i140
i158
i116
iNo
i4/23/2023
IBEW
Local 648 Pension Plan
i31-6134845-i001
iYellow
as of i2/28/2020
iYellow as of i2/28/2019
iImplemented
i526
i728
i2,175
iNo
i8/29/2021
IBEW
Local 82 Pension Plan
i31-6127268-i001
iGreen
as of i6/30/2020
iGreen as of i6/30/2019
iNo
i1,373
i1,662
i1,569
iNo
i12/3/2023
Idaho
Plumbers and Pipefitters Pension Plan
i82-6010346-i001
iGreen
as of i5/31/2020
iGreen as of i5/31/2019
iNo
i1,370
i1,307
i1,247
iNo
i3/31/2023
Minnesota
Teamsters Construction Division Pension Fund
i41-6187751-i001
iGreen
as of i11/30/2019
iGreen as of i11/30/2018
iNo
i663
i673
i740
iNo
i4/30/2021
National
Automatic Sprinkler Industry Pension Fund
i52-6054620-i001
iRed
iRed
iImplemented
i954
i1,074
i738
iNo
i3/31/2021-
i7/31/2024
National Electrical Benefit Fund
i53-0181657-i001
iGreen
iGreen
iNo
i14,484
i12,679
i8,468
iNo
i12/31/2021-
i8/30/2025
Pension Trust Fund for Operating Engineers
i94-6090764-i001
iYellow
iYellow
iImplemented
i2,680
i2,598
i2,403
iNo
i6/15/2022-
i6/30/2023
Sheet Metal Workers Pension Plan of Southern CA, AZ, and NV
i95-6052257-i001
iYellow
iYellow
iImplemented
i3,255
i2,119
i1,774
iNo
i6/30/2024
Southwest
Marine Pension Trust
i95-6123404-i001
iRed
iRed
iImplemented
i170
i132
i81
iNo
i1/31/2024
Other
funds
i30,931
i24,512
i21,421
Total
contributions
$
i85,444
$
i72,525
$
i58,722
* Plan
includes contributions required by collective bargaining agreements which have expired, but contain provisions automatically renewing their terms in the absence of a subsequent negotiated agreement.
/
MDU Resources Group, Inc. Form 10-K 99
Part
II
The Company was listed in the plans' Forms 5500 as providing more than 5 percent of the total contributions for the following plans and plan years:
Pension Fund
Year Contributions to Plan Exceeded More Than 5 Percent of Total Contributions (as of December 31 of the Plan's Year-End)
Edison Pension Plan
2019
and 2018
IBEW Local 82 Pension Plan
2019 and 2018
IBEW Local 124 Pension Trust Fund
2019 and 2018
IBEW Local 212 Pension Trust Fund
2019 and 2018
IBEW Local 357 Pension Plan A
2019 and 2018
IBEW Local 648 Pension Plan
2019 and 2018
IBEW Local 683 Pension Fund Pension Plan
2019
IBEW
Local Union No 226 Open End Pension Fund
2019 and 2018
Idaho Plumbers and Pipefitters Pension Plan
2019 and 2018
International Union of Operating Engineers Local 701 Pension Trust Fund
2019 and 2018
Minnesota Teamsters Construction Division Pension Fund
2019 and 2018
Pension and Retirement Plan of Plumbers and Pipefitters Local 525
2019 and 2018
The
Company also contributes to a number of multiemployer other postretirement plans under the terms of collective-bargaining agreements that cover its union-represented employees. These plans provide benefits such as health insurance, disability insurance and life insurance to retired union employees. Many of the multiemployer other postretirement plans are combined with active multiemployer health and welfare plans. The Company's total contributions to its multiemployer other postretirement plans, which also includes contributions to active multiemployer health and welfare plans, were $i63.8
million, $i59.5 million and $i51.9 million for the years ended December 31,
2020, 2019 and 2018, respectively.
Amounts contributed in 2020, 2019 and 2018 to defined contribution multiemployer plans were $i54.2 million, $i49.2
million and $i31.1 million, respectively.
Note 19 - iJointly
Owned Facilities
The consolidated financial statements include the Company's ownership interests in three coal-fired electric generating facilities (Big Stone Station, Coyote Station and Wygen III) and one major transmission line (BSSE). Each owner of the jointly owned facilities is responsible for financing its investment. The Company's share of the jointly owned facilities operating expenses was reflected in the appropriate categories of operating expenses (electric fuel and purchased power; operation and maintenance; and taxes, other than income) in the Consolidated Statements of Income.
i
At
December 31, the Company's share of the cost of utility plant in service, construction work in progress and related accumulated depreciation for the jointly owned facilities was as follows:
Ownership Percentage
2020
2019
(In thousands)
Big
Stone Station:
i22.7
%
Utility plant in service
$
i155,967
$
i152,836
Construction
work in progress
i104
i518
Less
accumulated depreciation
i45,435
i46,266
$
i110,636
$
i107,088
BSSE:
i50.0
%
Utility
plant in service
$
i107,442
$
i105,767
Construction
work in progress
i—
i—
Less
accumulated depreciation
i2,682
i1,232
$
i104,760
$
i104,535
Coyote
Station:
i25.0
%
Utility plant in service
$
i159,784
$
i160,235
Construction
work in progress
i323
i21
Less
accumulated depreciation
i108,852
i107,638
$
i51,255
$
i52,618
Wygen
III:
i25.0
%
Utility plant in service
$
i66,101
$
i67,869
Construction
work in progress
i232
i112
Less
accumulated depreciation
i10,038
i10,482
$
i56,295
$
i57,499
/
100 MDU
Resources Group, Inc. Form 10-K
Part II
Note 20 - iRegulatory
Matters
The Company regularly reviews the need for electric and natural gas rate changes in each of the jurisdictions in which service is provided. The Company files for rate adjustments to seek recovery of operating costs and capital investments, as well as reasonable returns as allowed by regulators. Certain regulatory proceedings and cases may also contain recurring mechanisms that can have an annual true-up. Examples of these recurring mechanisms include: infrastructure riders, transmission trackers, renewable resource cost adjustment riders, as well as weather normalization and decoupling mechanisms. The following paragraphs summarize the Company's significant regulatory proceedings
and cases by jurisdiction, including the status of each open request. The Company is unable to predict the ultimate outcome of these matters, the timing of final decisions of the various regulators and courts, or the effect on the Company's results of operations, financial position or cash flows.
MNPUC
On September 27, 2019, Great Plains filed an application with the MNPUC for a natural gas rate increase of approximately $i2.9 million
annually or approximately i12.0 percent above current rates. The requested increase was primarily to recover investments in facilities to enhance safety and reliability and the depreciation and taxes associated with the increase in investment. On November 22, 2019, Great Plains received approval to implement an interim rate increase of approximately $i2.6 million
or approximately i11.0 percent, subject to refund, effective January 1, 2020. On October 26, 2020, the MNPUC issued an order authorizing an annual increase in revenues of approximately $i2.6 million
or approximately i11.5 percent. This matter is pending before the MNPUC.
MTPSC
On May 8, 2020, Montana-Dakota filed a request with the MTPSC to use deferred accounting for costs related to the COVID-19 pandemic. The filing was withdrawn by Montana-Dakota on January 25, 2021.
On June 22,
2020, Montana-Dakota filed an application with the MTPSC for a natural gas rate increase of approximately $i8.6 million annually or approximately i13.4 percent
above current rates. The requested increase was primarily to recover investments in facilities that were made to enhance system safety and reliability, as well as the depreciation, taxes and operation and maintenance costs associated with this increase in investment. On January 14, 2021, Montana-Dakota received approval to implement an interim rate increase of approximately $i4.9 million or approximately i7.7 percent,
subject to refund, effective February 1, 2021. On February 1, 2021, Montana-Dakota filed a stipulation and settlement agreement with the MTPSC reflecting an updated increase of approximately $i7.3 million annually or approximately i11.4
percent above current rates. On February 16, 2021, the MTPSC approved the settlement with rates effective on or after March 15, 2021.
NDPSC
On April 24, 2020, Montana-Dakota filed a request with the NDPSC to use deferred accounting for costs related to the COVID-19 pandemic. On February 3, 2021, the NDPSC approved this request with an accounting order to track expenses and revenues related to the COVID-19 pandemic. This order had an effective date of April 24, 2020.
On August 26, 2020, Montana-Dakota filed an application with the NDPSC for a natural gas rate
increase of approximately $i9.0 million annually or approximately i7.8 percent
above current rates. The requested increase was primarily to recover investments in facilities to enhance system safety and reliability and the depreciation and taxes associated with the increase in investment. On December 16, 2020, Montana-Dakota received approval to implement an interim rate increase of approximately $i6.9 million or approximately i6.0 percent,
subject to refund, effective January 1, 2021. A hearing is scheduled for March 17, 2021. This matter is pending before the NDPSC.
Montana-Dakota has a renewable resource cost adjustment rate tariff that allows for annual adjustments for recent projected capital costs and related expenses for projects determined to be recoverable under the tariff. On November 2, 2020, Montana-Dakota filed an annual update to its renewable resource cost adjustment requesting to recover a revised revenue requirement of approximately $i14.4 million
annually, not including the prior period true-up adjustment. The update reflects a decrease of approximately $i300,000 from the revenues currently included in rates. On January 6, 2021, the NDPSC approved the increase with rates effective February 1, 2021.
OPUC
On March 31,
2020, Cascade filed a natural gas general rate case with the OPUC requesting an increase in annual revenue of approximately $i4.9 million or approximately i7.2 percent,
which included a request for an additional recovery of environmental remediation deferred costs of approximately $i364,000. On September 30, 2020, Cascade filed a settlement agreement with the OPUC reflecting an annual increase in revenues of approximately $i3.2 million
or approximately i4.8 percent. On January 6, 2021, the filing was approved with rates effective February 1, 2021. On January 21, 2021, Cascade submitted a compliance filing using final costs for plant additions which resulted in a final increase in revenues of approximately $i2.9
million or approximately i4.3 percent.
WUTC
On May 27, 2020, Cascade filed a request with the WUTC to use deferred accounting for costs related to the COVID-19 pandemic. On December 10, 2020, the WUTC approved this request.
MDU
Resources Group, Inc. Form 10-K 101
Part II
On June 19, 2020, Cascade filed an application with the WUTC for a natural gas rate increase of approximately $i13.8 million
annually or approximately i5.3 percent above current rates. The requested increase was primarily to recover investments made in infrastructure upgrades, as well as increased operation and maintenance costs. Cascade updated its filing on July 24, 2020, to approximately $i14.3 million
annually or approximately i5.5 percent. Cascade filed a rebuttal case on January 8, 2021, supporting an increase of approximately $i7.4 million
annually or approximately i2.8 percent. The revised revenue within the rebuttal case reflects several adjustments including depreciation, reduction to return on equity, delays on certain projects, adjustments to income taxes and updates to wages. The WUTC has 11 months to render a final decision on the rate case. A hearing is scheduled for February 24, 2021. This matter is pending before the WUTC.
FERC
On
September 1, 2020, Montana-Dakota filed an update to its transmission formula rate under the MISO tariff for its multi-value project for $i12.9 million, which is effective January 1, 2021.
Note 21 - iCommitments
and Contingencies
iThe Company is party to claims and lawsuits arising out of its business and that of its consolidated subsidiaries, which may include, but are not limited to, matters involving property damage, personal injury, and environmental, contractual, statutory and regulatory obligations. The Company accrues a liability
for those contingencies when the incurrence of a loss is probable and the amount can be reasonably estimated. If a range of amounts can be reasonably estimated and no amount within the range is a better estimate than any other amount, then the minimum of the range is accrued. The Company does not accrue liabilities when the likelihood that the liability has been incurred is probable but the amount cannot be reasonably estimated or when the liability is believed to be only reasonably possible or remote. For contingencies where an unfavorable outcome is probable or reasonably possible and which are material, the Company discloses the nature of the contingency and, in some circumstances, an estimate of the possible loss. Accruals are based on the best information available, but in certain situations management
is unable to estimate an amount or range of a reasonably possible loss including, but not limited to when: (1) the damages are unsubstantiated or indeterminate, (2) the proceedings are in the early stages, (3) numerous parties are involved, or (4) the matter involves novel or unsettled legal theories.
At December 31, 2020 and 2019, the Company accrued liabilities which have not been discounted, including liabilities held for sale, of $i41.5 million
and $i29.1 million, respectively. At December 31, 2020 and 2019, the Company also recorded corresponding insurance receivables of $i17.5 million
and $i16.2 million, respectively, and regulatory assets of $i21.3 million and $i10.5 million,
respectively, related to the accrued liabilities. The accruals are for contingencies, including litigation, production taxes, royalty claims and environmental matters. This includes amounts that have been accrued for matters discussed in Environmental matters within this note. The Company will continue to monitor each matter and adjust accruals as might be warranted based on new information and further developments. Management believes that the outcomes with respect to probable and reasonably possible losses in excess of the amounts accrued, net of insurance recoveries, while uncertain, either cannot be estimated or will not have a material effect upon the Company's financial position, results of operations or cash flows. Unless otherwise required by GAAP, legal costs are expensed as they are incurred.
Environmental
matters
Portland Harbor Site In December 2000, Knife River - Northwest was named by the EPA as a PRP in connection with the cleanup of the riverbed site adjacent to a commercial property site acquired by Knife River - Northwest from Georgia-Pacific West, Inc. along the Willamette River. The riverbed site is part of the Portland, Oregon, Harbor Superfund Site where the EPA wants responsible parties to share in the costs of cleanup. To date, costs of the overall remedial investigation and feasibility study of the harbor site are being recorded, and initially paid, through an administrative consent order by the LWG. Investigative costs are indicated to be in excess of $i100 million.
The EPA issued an ROD in January 2017 adopting a selected remedy which is expected to take 13 years to complete with a then estimated present value of approximately $i1 billion. Corrective action will not be taken until remedial design/remedial action plans are approved by the EPA. Knife River - Northwest was also notified that the Portland Harbor Natural Resource Trustee Council intends to perform an injury assessment to natural resources resulting from the release of hazardous substances at the Harbor Superfund Site. It is not possible to estimate the costs of
natural resource damages until an assessment is completed and allocations are undertaken.
At this time, Knife River - Northwest does not believe it is a responsible party and has notified Georgia-Pacific West, Inc., that it intends to seek indemnity for liabilities incurred in relation to the above matters pursuant to the terms of their sale agreement. Knife River - Northwest has entered into an agreement tolling the statute of limitations in connection with the LWG's potential claim for contribution to the costs of the remedial investigation and feasibility study. LWG has stated its intent to file suit against Knife River - Northwest and others to recover LWG's investigation costs to the extent Knife River - Northwest cannot demonstrate its non-liability for the contamination or is unwilling to participate in an alternative dispute resolution process that has been established to address the matter. At this time, Knife River -
Northwest has agreed to participate in the alternative dispute resolution process.
The Company believes it is not probable that it will incur any material environmental remediation costs or damages in relation to the above referenced matter.
Manufactured Gas Plant Sites Claims have been made against Cascade for cleanup of environmental contamination at manufactured gas plant sites operated by Cascade's predecessors and a similar claim has been made against Montana-Dakota for a site operated by Montana-Dakota and its predecessors. Any accruals related to these claims are reflected in regulatory assets. For more information, see Note 6.
102 MDU
Resources Group, Inc. Form 10-K
Part II
Demand has been made of Montana-Dakota to participate in investigation and remediation of environmental contamination at a site in Missoula, Montana. The site operated as a former manufactured gas plant from approximately 1907 to 1938 when it was converted to a butane-air plant that operated until 1956. Montana-Dakota or its predecessors owned or controlled the site for a period of the time it operated as a manufacturedgas plant and Montana-Dakota operated the butane-air plant from
1940 to 1951, at which time it sold the plant. There are no documented wastes or by-products resulting from the mixing or distribution of butane-air gas. Preliminary assessment of a portion of the site provided a recommended remedial alternative for that portion of approximately $i560,000. However, the recommended remediation would not address any potential contamination to adjacent parcels that may be impacted by contamination from the manufactured gas plant. An environmental assessment was started in 2020, which is estimated to cost approximately
$i800,000. Montana-Dakota and another party agreed to voluntarily investigate and remediate the site and that Montana-Dakota will pay two-thirds of the costs for further investigation and remediation of the site. Montana-Dakota has accrued costs of $i800,000
for the remediation and investigation costs, and has incurred costs of $i130,000 as of December 31, 2020. Montana-Dakota received notice from a prior insurance carrier that it will participate in payment of defense costs incurred in relation to the claim.
A claim was made against Cascade for contamination at the Bremerton Gasworks Superfund Site in Bremerton, Washington, which was received in 1997. A preliminary investigation has found soil and
groundwater at the site contain contaminants requiring further investigation and cleanup. The EPA conducted a Targeted Brownfields Assessment of the site and released a report summarizing the results of that assessment in August 2009. The assessment confirmed that contaminants have affected soil and groundwater at the site, as well as sediments in the adjacent Port Washington Narrows. In April 2010, the Washington DOE issued notice it considered Cascade a PRP for hazardous substances at the site. In May 2012, the EPA added the site to the National Priorities List of Superfund sites. Cascade entered into an administrative settlement agreement and consent order with the EPA regarding the scope and schedule for a remedial investigation and feasibility study for the site. Current estimates for the cost to complete the remedial investigation and feasibility study are approximately $i7.6 million
of which $i5.0 million has been incurred as of December 31, 2020. Based on the site investigation, preliminary remediation alternative costs were provided by consultants in August 2020; therefore, the accrual for these costs was increased in the third quarter of 2020 by $i11.1 million.
The preliminary information received through the completion of the data report allowed for the projection of possible costs for a variety of site configurations, remedial measures and potential natural resource damage claims of between $i13.6 million and $i71.0 million.
At December 31, 2020, Cascade has accrued $i2.6 million for the remedial investigation and feasibility study, as well as $i17.5 million
for remediation of this site. The accrual for remediation cost will be reviewed and adjusted, if necessary, after the completion of the feasibility study. In April 2010, Cascade filed a petition with the WUTC for authority to defer the costs incurred in relation to the environmental remediation of this site. The WUTC approved the petition in September 2010, subject to conditions set forth in the order.
A claim was made against Cascade for contamination at a site in Bellingham, Washington. Cascade received notice from a party in May 2008 that Cascade may be a PRP, along with other parties, for contamination from a manufactured gas plant owned by Cascade and its predecessor from about 1946 to 1962. Other PRPs reached an agreed order and work plan with the Washington DOE for completion of a remedial investigation and feasibility study for the site. A feasibility study prepared for one of the PRPs in March 2018 identifies five cleanup
action alternatives for the site with estimated costs ranging from $i8.0 million to $i20.4 million
with a selected preferred alternative having an estimated total cost of $i9.3 million. The other PRPs will develop a cleanup action plan and, after public review of the cleanup action plan, develop design documents. Cascade believes its proportional share of any liability will be relatively small in comparison to other PRPs. The plant manufactured gas from coal between approximately 1890 and 1946. In 1946, shortly after Cascade's predecessor acquired the plant, the plant converted to
a propane-air gas facility. There are no documented wastes or by-products resulting from the mixing or distribution of propane-air gas. Cascade has recorded an accrual for this site for an amount that is not material.
The Company has received notices from and entered into agreement with certain of its insurance carriers that they will participate in defense for certain contamination claims subject to full and complete reservations of rights and defenses to insurance coverage. To the extent these claims are not covered by insurance, the Company intends to seek recovery of remediation costs through its natural gas rates charged to customers.
Purchase commitments
The
Company has entered into various commitments largely consisting of contracts for natural gas and coal supply; purchased power; natural gas transportation and storage; royalties; information technology; and construction materials. Certain of these contracts are subject to variability in volume and price. iThe commitment terms vary in length, up to i39 years.
The commitments under these contracts as of December 31, 2020, were:/
2021
2022
2023
2024
2025
Thereafter
(In
thousands)
Purchase commitments
$
i458,397
$
i235,858
$
i173,306
$
i124,724
$
i98,894
$
i691,613
These
commitments were not reflected in the Company's consolidated financial statements. Amounts purchased under various commitments for the years ended December 31, 2020, 2019 and 2018, were $i666.0 million, $i686.5 million and
$i548.0 million, respectively.
Guarantees
In 2009, multiple sale agreements were signed to sell the Company's ownership interests in the Brazilian Transmission Lines. In connection with the sale, Centennial agreed to guarantee payment of any indemnity obligations of certain of the
Company's indirect wholly owned subsidiaries. The
MDU Resources Group, Inc. Form 10-K 103
Part II
remaining guarantee is expected to expire in 2021. The guarantees were required by the buyers as a condition to the sale of the Brazilian Transmission Lines.
Certain
subsidiaries of the Company have outstanding guarantees to third parties that guarantee the performance of other subsidiaries of the Company. These guarantees are related to construction contracts, insurance deductibles and loss limits, and certain other guarantees. At December 31, 2020, the fixed maximum amounts guaranteed under these agreements aggregated $i212.4 million.
Certain of the guarantees also have no fixed maximum amounts specified. The amounts of scheduled expiration of the maximum amounts guaranteed under these agreements aggregate to $i178.6 million in 2021; $i16.1 million
in 2022; $i7.0 million in 2023; $i500,000 in 2024; $i500,000
in 2025; $i700,000 thereafter; and $i9.0 million, which has no scheduled maturity date. There were ino
amounts outstanding under the previously mentioned guarantees at December 31, 2020. In the event of default under these guarantee obligations, the subsidiary issuing the guarantee for that particular obligation would be required to make payments under its guarantee.
Certain subsidiaries have outstanding letters of credit to third parties related to insurance policies and other agreements, some of which are guaranteed by other subsidiaries of the Company. At December 31, 2020, the fixed maximum amounts guaranteed under these letters of credit aggregated $i22.7 million.
The amounts of scheduled expiration of the maximum amounts guaranteed under these letters of credit aggregate to $i22.2 million in 2021 and $i500,000
in 2022. There were ino amounts outstanding under the previously mentioned letters of credit at December 31, 2020. In the event of default under these letter of credit obligations, the subsidiary guaranteeing the letter of credit would be obligated for reimbursement of payments made under the letter of credit.
In addition, Centennial, Knife River and MDU Construction Services have issued guarantees to third parties related to the routine purchase of maintenance items,
materials and lease obligations for which no fixed maximum amounts have been specified. These guarantees have no scheduled maturity date. In the event a subsidiary of the Company defaults under these obligations, Centennial, Knife River or MDU Construction Services would be required to make payments under these guarantees. Any amounts outstanding by subsidiaries of the Company were reflected on the Consolidated Balance Sheet at December 31, 2020.
In the normal course of business, Centennial has surety bonds related to construction contracts
and reclamation obligations of its subsidiaries. In the event a subsidiary of Centennial does not fulfill a bonded obligation, Centennial would be responsible to the surety bond company for completion of the bonded contract or obligation. A large portion of the surety bonds is expected to expire within the next 12 months; however, Centennial will likely continue to enter into surety bonds for its subsidiaries in the future. At December 31, 2020, approximately $i953.9 million
of surety bonds were outstanding, which were not reflected on the Consolidated Balance Sheet.
Variable interest entities
The Company evaluates its arrangements and contracts with other entities to determine if they are VIEs and if so, if the Company is the primary beneficiary.
Fuel Contract Coyote Station entered into a coal supply agreement with Coyote Creek that provides for the purchase of coal necessary to supply the coal requirements of the Coyote Station for the period May 2016 through
December 2040. Coal purchased under the coal supply agreement is reflected in inventories on the Consolidated Balance Sheets and is recovered from customers as a component of electric fuel and purchased power.
The coal supply agreement creates a variable interest in Coyote Creek due to the transfer of all operating and economic risk to the Coyote Station owners, as the agreement is structured so that the price of the coal will cover all costs of operations, as well as future reclamation costs. The Coyote Station owners are also providing a guarantee of the value of the assets of Coyote Creek as they would be required to buy the assets at book value should they terminate the contract prior to the end of the contract term and are providing a guarantee
of the value of the equity of Coyote Creek in that they are required to buy the entity at the end of the contract term at equity value. Although the Company has determined that Coyote Creek is a VIE, the Company has concluded that it is not the primary beneficiary of Coyote Creek because the authority to direct the activities of the entity is shared by the four unrelated owners of the Coyote Station, with no primary beneficiary existing. As a result, Coyote Creek is not required to be consolidated in the Company's financial statements.
The following unaudited information shows selected items by quarter for the years 2020 and 2019:
First
Quarter
Second Quarter
Third Quarter
Fourth Quarter
(In
thousands, except per share amounts)
2020
Operating revenues
$
i1,197,373
$
i1,362,928
$
i1,587,289
$
i1,385,160
Operating
expenses
i1,140,303
i1,224,674
i1,383,578
i1,239,270
Operating
income
i57,070
i138,254
i203,711
i145,890
Income
from continuing operations
i25,539
i99,842
i153,015
i112,131
Income
(loss) from discontinued operations, net of tax
(i409)
(i139)
i63
i163
Net
income
i25,130
i99,703
i153,078
i112,294
Earnings
per share - basic:
Income from continuing operations
i.13
i.50
i.76
i.56
Discontinued
operations, net of tax
i—
i—
i—
i—
Earnings
per share - basic
i.13
i.50
i.76
i.56
Earnings
per share - diluted:
Income from continuing operations
i.13
i.50
i.76
i.56
Discontinued
operations, net of tax
i—
i—
i—
i—
Earnings
per share - diluted
i.13
i.50
i.76
i.56
Weighted
average common shares outstanding:
Basic
i200,440
i200,522
i200,522
i200,522
Diluted
i200,456
i200,539
i200,619
i200,923
2019
Operating
revenues
$
i1,091,191
$
i1,303,573
$
i1,563,799
$
i1,378,213
Operating
expenses
i1,026,973
i1,206,262
i1,374,329
i1,247,992
Operating
income
i64,218
i97,311
i189,470
i130,221
Income
from continuing operations
i41,089
i63,145
i136,128
i94,804
Income
(loss) from discontinued operations, net of tax
(i163)
(i1,320)
i1,509
i261
Net
income
i40,926
i61,825
i137,637
i95,065
Earnings
per share - basic:
Income from continuing operations
i.21
i.32
i.68
i.47
Discontinued
operations, net of tax
i—
(i.01)
i.01
i—
Earnings
per share - basic
i.21
i.31
i.69
i.47
Earnings
per share - diluted:
Income from continuing operations
i.21
i.32
i.68
i.47
Discontinued
operations, net of tax
i—
(i.01)
i.01
i—
Earnings
per share - diluted
i.21
i.31
i.69
i.47
Weighted
average common shares outstanding:
Basic
i196,401
i198,270
i199,343
i200,383
Diluted
i196,414
i198,287
i199,383
i200,478
/
Certain
operations of the Company are highly seasonal and revenues from and certain expenses for such operations may fluctuate significantly among quarterly periods. Accordingly, quarterly financial information may not be indicative of results for a full year.
/
MDU Resources Group, Inc. Form 10-K 105
Part
II
Definitions
The following abbreviations and acronyms used in Notes to Consolidated Financial Statements are defined below:
Abbreviation or Acronym
AFUDC
Allowance for funds used during construction
ASC
FASB
Accounting Standards Codification
ASU
FASB Accounting Standards Update
Big Stone Station
475-MW coal-fired electric generating facility near Big Stone City, South Dakota (22.7 percent ownership)
Brazilian Transmission Lines
Company's former investment in companies owning three electric transmission lines in Brazil
BSSE
345-kilovolt transmission line from Ellendale, North Dakota, to Big Stone City, South Dakota (50 percent ownership)
Btu
British
thermal unit
Cascade
Cascade Natural Gas Corporation, an indirect wholly owned subsidiary of MDU Energy Capital
Centennial
Centennial Energy Holdings, Inc., a direct wholly owned subsidiary of the Company
Centennial Capital
Centennial Holdings Capital LLC, a direct wholly owned subsidiary of Centennial
Centennial's Consolidated EBITDA
Centennial's consolidated net income from continuing operations plus the
related interest expense, taxes, depreciation, depletion, amortization of intangibles and any non-cash charge relating to asset impairment for the preceding 12-month period
Centennial Resources
Centennial Energy Resources LLC, a direct wholly owned subsidiary of Centennial
Company
MDU Resources Group, Inc. (formerly known as MDUR Newco), which, as the context requires, refers to the previous MDU Resources Group, Inc. prior to January 1, 2019, and the new holding company of the same name after January 1, 2019
COVID-19
Coronavirus
disease 2019
Coyote Creek
Coyote Creek Mining Company, LLC, a subsidiary of The North American Coal Corporation
Coyote Station
427-MW coal-fired electric generating facility near Beulah, North Dakota (25 percent ownership)
Dakota Prairie Refining
Dakota Prairie Refining, LLC, a limited liability company previously owned by WBI Energy and Calumet Specialty Products Partners, L.P. (previously included in the Company's refining segment)
EBITDA
Earnings
before interest, taxes, depreciation, depletion and amortization
EIN
Employer Identification Number
EPA
United States Environmental Protection Agency
FASB
Financial Accounting Standards Board
FERC
Federal Energy Regulatory Commission
Fidelity
Fidelity Exploration & Production Company, a direct wholly owned subsidiary of WBI Holdings (previously referred to as the
Company's exploration and production segment)
FIP
Funding improvement plan
GAAP
Accounting principles generally accepted in the United States of America
Great Plains
Great Plains Natural Gas Co., a public utility division of the Company prior to the closing of the Holding Company Reorganization and a public utility division of Montana-Dakota as of January 1, 2019
Holding Company Reorganization
The
internal holding company reorganization completed on January 1, 2019, pursuant to the agreement and plan of merger, dated as of December 31, 2018, by and among Montana-Dakota, the Company and MDUR Newco Sub, which resulted in the Company becoming a holding company and owning all of the outstanding capital stock of Montana-Dakota.
IBEW
International Brotherhood of Electrical Workers
Intermountain
Intermountain
Gas Company, an indirect wholly owned subsidiary of MDU Energy Capital
Knife River
Knife River Corporation, a direct wholly owned subsidiary of Centennial
Knife River - Northwest
Knife River Corporation - Northwest, an indirect wholly owned subsidiary of Knife River
K-Plan
Company's 401(k) Retirement Plan
LIBOR
London Inter-bank Offered Rate
LWG
Lower Willamette Group
MDU
Construction Services
MDU Construction Services Group, Inc., a direct wholly owned subsidiary of Centennial
MDU Energy Capital
MDU Energy Capital, LLC, a direct wholly owned subsidiary of the Company
MDUR Newco
MDUR Newco, Inc., a public holding company created by implementing the Holding Company Reorganization, now known as the Company
MDUR Newco Sub
MDUR Newco Sub, Inc., a direct, wholly
owned subsidiary of MDUR Newco, which was merged with and into Montana-Dakota in the Holding Company Reorganization
106 MDU Resources Group, Inc. Form 10-K
Part II
MEPP
Multiemployer
pension plan
MISO
Midcontinent Independent System Operator, Inc.
MMBtu
Million Btu
MNPUC
Minnesota Public Utilities Commission
Montana-Dakota
Montana-Dakota Utilities Co. (formerly known as MDU Resources Group, Inc.), a public utility division of the Company prior to the closing of the Holding Company Reorganization and a direct wholly owned subsidiary of MDU Energy Capital as of January
1, 2019
MTPSC
Montana Public Service Commission
MW
Megawatt
NDPSC
North Dakota Public Service Commission
OPUC
Oregon Public Utility Commission
PRP
Potentially Responsible Party
ROD
Record of Decision
RP
Rehabilitation
plan
SDPUC
South Dakota Public Utilities Commission
SEC
United States Securities and Exchange Commission
Securities Act
Securities Act of 1933, as amended
SOFR
Secured Overnight Financing Rate
TCJA
Tax Cuts and Jobs Act
VIE
Variable interest entity
Washington
DOE
Washington State Department of Ecology
WBI Energy Transmission
WBI Energy Transmission, Inc., an indirect wholly owned subsidiary of WBI Holdings
WBI Holdings
WBI Holdings, Inc., a direct wholly owned subsidiary of Centennial
WUTC
Washington Utilities and Transportation Commission
Wygen III
100-MW coal-fired electric generating facility near Gillette, Wyoming (25 percent ownership)
WYPSC
Wyoming
Public Service Commission
MDU Resources Group, Inc. Form 10-K 107
Part II
Item 9. Changes in and Disagreements With Accountants on Accounting and Financial Disclosure
None.
Item 9A.
Controls and Procedures
The following information includes the evaluation of disclosure controls and procedures by the Company's chief executive officer and the chief financial officer, along with any significant changes in internal controls of the Company.
Evaluation of Disclosure Controls and Procedures
The term "disclosure controls and procedures" is defined in Rules 13a-15(e) and 15d-15(e) under the Exchange Act. The Company's disclosure controls and other procedures are designed to provide reasonable assurance that information required to be disclosed in the reports that the
Company files or submits under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the SEC's rules and forms. The Company's disclosure controls and other procedures are designed to provide reasonable assurance that information required to be disclosed is accumulated and communicated to management, including the Company's chief executive officer and chief financial officer, to allow timely decisions regarding required disclosure. The Company's management, with the participation of the Company's chief executive officer and chief financial officer, has evaluated the effectiveness of the
Company's disclosure controls and other procedures as of the end of the period covered by this report. Based upon that evaluation, the chief executive officer and the chief financial officer have concluded that, as of the end of the period covered by this report, such controls and procedures were effective at a reasonable assurance level.
Changes in Internal Controls
No change in the Company's internal control over financial reporting (as defined in Rules 13a-15(f) and 15d-15(f) under the Exchange Act) occurred during the three months ended December 31, 2020, that has materially affected, or is reasonably likely to materially affect, the Company's internal control over financial
reporting.
Management's Annual Report on Internal Control Over Financial Reporting
The information required by this item is included in this Form 10-K at Item 8 - Management's Report on Internal Control Over Financial Reporting.
Attestation Report of the Registered Public Accounting Firm
The information required by this item is included in this Form 10-K at Item 8 - Report of Independent Registered Public Accounting Firm.
Item 9B. Other Information
None.
108 MDU
Resources Group, Inc. Form 10-K
Part III
Item 10. Directors, Executive Officers and Corporate Governance
Item 12. Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters
Equity Compensation Plan Information
The following
table includes information as of December 31, 2020, with respect to the Company's equity compensation plans:
Plan Category
(a) Number of securities to be issued upon exercise of outstanding options, warrants and rights
(b) Weighted
average exercise price of outstanding options, warrants and rights
(c) Number of securities remaining available for future issuance under equity compensation plans (excluding securities reflected in column (a))
Equity compensation plans approved by stockholders (1)
613,174
(2)
$
—
(3)
3,555,471
(4)(5)
Equity
compensation plans not approved by stockholders
N/A
N/A
N/A
Total
613,174
$
—
3,555,471
(1) Consists of the Non-Employee Director Long-Term Incentive Compensation Plan and the Long-Term Performance-Based Incentive Plan.
(2) Consists
of performance share awards.
(3) No weighted average exercise price is shown for the performance share awards because such awards have no exercise price.
(4) This amount includes 3,328,721 shares available for future issuance under the Long-Term Performance-Based Incentive Plan in connection with grants of restricted stock, performance units, performance shares or other equity-based awards.
(5) This amount includes 226,750 shares available for future issuance under the Non-Employee Director Long-Term Incentive Compensation Plan.
All other schedules have been omitted because they are not applicable or the required information is included elsewhere in the financial statements or related notes.
The
accompanying notes are an integral part of these condensed financial statements.
Notes to Condensed Financial Statements
Note 1 - Summary of Significant Accounting Policies
Basis of presentationThe condensed financial information reported in Schedule I is being presented to comply with Rule 12-04 of Regulation S-X. The information is unconsolidated and is presented for the parent company only, MDU Resources Group, Inc. (the Company) as of and for the years ended December 31,
2020 and 2019. Prior to the Holding Company Reorganization, the Company included Montana-Dakota and Great Plains, public utility divisions of the Company as of December 31, 2018. On January 2, 2019, the Company announced the completion of the Holding Company Reorganization, which resulted in Montana-Dakota and Great Plains becoming a subsidiary of the Company. Immediately after consummation, the Company had,
on a consolidated basis, the same assets, businesses and operations as it had immediately prior to the reorganization. For more information on the reorganization, see Item 8 - Note 1. The prior periods have not been restated and reflect the condensed financial information of Montana-Dakota and Great Plains as of and for the year ended December 31, 2018. Due to the completion of the Holding Company Reorganization, the presentation of the year ended December 31, 2018, will vary from that of and for the years ended December 31, 2020 and 2019. In Schedule I, investments in subsidiaries are presented under the equity method of accounting where the assets and liabilities of the subsidiaries
are not consolidated. The investments in net assets of the subsidiaries are recorded on the Condensed Balance Sheets. The income from subsidiaries is reported as equity in earnings of subsidiaries on the Condensed Statements of Income. The material cash inflows on the Condensed Statements of Cash Flows are primarily from the dividends and other payments received from its subsidiaries and the proceeds raised from the issuance of equity securities. The consolidated financial statements of MDU Resources Group, Inc. reflect certain businesses as discontinued operations. These statements should be read in conjunction with
the consolidated financial statements and notes thereto of MDU Resources Group, Inc.
Earnings per common share Please refer to the Consolidated Statements of Income of the registrant for earnings per common share. In addition, see Item 8 - Note 2 for information on the computation of earnings per common share.
Note 2 - Debt At December 31, 2020, the Company had no long-term debt maturities. For more information on debt, see Item 8 - Note 9.
Note 3 - Dividends The Company depends
on earnings and dividends from its subsidiaries to pay dividends on common stock. Cash dividends paid to the Company by subsidiaries were $i228.4 million, $i177.1 million and
$i115.9 million for the years ended December 31, 2020, 2019 and 2018, respectively.
XBRL Instance Document - the instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document
* Schedules and exhibits to this agreement have been omitted pursuant to Item 601(a)(5) of Regulation S-K. A copy of any omitted schedule and/or exhibit will be furnished as a supplement to the SEC upon
request.
+ Management contract, compensatory plan or arrangement.
MDU Resources Group, Inc. agrees to furnish to the SEC upon request any instrument with respect to long-term debt that MDU Resources Group, Inc. has not filed as an exhibit pursuant to the exemption provided by Item 601(b)(4)(iii)(A) of Regulation S-K.
Item 16. Form 10-K Summary
None.
116 MDU
Resources Group, Inc. Form 10-K
Part IV
Signatures
Pursuant to the requirements of Section 13 or 15(d) 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.
Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the registrant in the capacities and on the date indicated.
