UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

 

 

FORM 6-K

 

 

REPORT OF FOREIGN PRIVATE ISSUER

PURSUANT TO RULE 13a-16 OR 15d-16

UNDER THE SECURITIES EXCHANGE ACT OF 1934

For the month of April, 2021

Commission File Number: 000-54516

 

 

Emera Incorporated

(Exact name of registrant as specified in its charter)

 

 

5151 Terminal Road

Halifax NS B3J 1A1

Canada

(Address of principal executive offices)

 

 

Indicate by check mark whether the registrant files or will file annual reports under cover of Form 20-F or Form 40-F.

Form 20-F  ☐             Form 40-F  ☒

Indicate by check mark if the registrant is submitting the Form 6-K in paper as permitted by Regulation S-T Rule 101(b)(1):  ☐

Indicate by check mark if the registrant is submitting the Form 6-K in paper as permitted by Regulation S-T Rule 101(b)(7):  ☐

 

 


SIGNATURES

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

 

    EMERA INCORPORATED
Date: April 9, 2021     By:          

/s/ Stephen D. Aftanas

      Name: Stephen D. Aftanas
      Title: Corporate Secretary


EXHIBIT INDEX

 

Exhibit No.            

  

Description

99.1    Emera Notice of Annual Meeting of Common Shareholders Thursday, May 20, 2021 and 2021 Management Information Circular
99.2    Emera 2020 Annual Report
99.3    Emera Form of Proxy relating to Emera’s May 20, 2021 meeting
99.4    Voting Instruction Form (VIF) relating to Emera’s May 20, 2021 shareholder meeting
99.5    Emera Notice and Access Notification to Registered Shareholders
99.6    Emera Notice and Access Notification to Non-Registered Shareholders
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Exhibit 99.1

 

EMERA INC.

NOTICE OF ANNUAL MEETING

OF COMMON

SHAREHOLDERS

AND MANAGEMENT

INFORMATION CIRCULAR

 

 

 

 

THURSDAY, MAY 20, 2021

 


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ABOUT EMERA

We’re a team of experts focused on safely delivering cleaner, affordable and reliable energy to our customers in Canada, the US and the Caribbean. Our Environmental, Social and Governance (“ESG”) commitments are core to our strategy and we’re leading the way to a cleaner energy future with clear climate goals and a vision to achieve net-zero carbon emissions by 2050. We primarily invest in regulated electric and gas utilities, driving predictable returns and steady growth for our investors, enabling us to reinvest in our teams, our companies and our communities.

TABLE OF CONTENTS

 

Notice of Annual Meeting

     4  

Management Information Circular

     5  

Business of the Meeting

     9  

Director Nominees

     10  

Skills and Experience

     11  

Statement of Corporate Governance Practices

     27  
A Letter from the Management Resources and Compensation Committee to Our Shareholders      50  

Statement of Executive Compensation

     53  

Compensation Discussion and Analysis

     60  

Performance Graph

     77  

NEO Summary Compensation Table

     79  

Appendix “A” – Board of Directors Charter

     94  
Appendix “B” – Resolution Amending the Senior Management Stock Option Plan      96  
 

 


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NOTICE OF ANNUAL MEETING OF COMMON SHAREHOLDERS AND MANAGEMENT INFORMATION CIRCULAR

 

FELLOW SHAREHOLDERS,

Despite the uncertainty and many unknowns, our team very effectively navigated the challenges of the COVID-19 pandemic to safely deliver the cleaner, affordable and reliable energy our customers count on while continuing to create value for shareholders. As essential service providers, we adapted quickly to deliver for our customers and communities in 2020.

We look forward to the opportunity to discuss Emera’s performance at our Annual Meeting of Shareholders on May 20, 2021. Outlined in this Circular, you will find information about the business to be conducted at our upcoming meeting, including details about our 2021 Director nominees. You will also find information about our approach to executive compensation and our commitment to strong corporate governance.

ADAPTING TO DELIVER IN A CHALLENGING YEAR

As the reality of a global pandemic became clear in the first quarter of 2020, the team adapted quickly to introduce new protocols and procedures to continue to safely deliver for our customers and stakeholders while keeping employees, customers and our communities safe.

The COVID-19 pandemic impacted the regions where we operate to varying degrees. While community spread was greater in some areas than others, the new protocols and the team’s commitment to safety successfully protected our employees with virtually no workplace spread of COVID-19. The team also stepped up to assist those most impacted by the pandemic through customer relief programs and community investments to support energy costs, food banks and mental health initiatives.

Despite the added challenges of the pandemic, the team continued to advance our strategy and execute on a $2.7 billion capital plan, the largest in Emera’s history. We completed the final phase of the more than 600MW of solar now in service for Tampa Electric, and started work on another 600MW. We advanced the modernization of Big Bend to reduce the use of coal at Tampa Electric. We continued to safely deploy smart meters in Nova Scotia, Florida and the Caribbean, with well over a million now in service. We also completed the Santa Fe Loop Project at New Mexico Gas, increasing pipeline capacity and improving reliability for customers. For additional details on Emera’s key operational accomplishments, see Emera’s 2020 Annual Report.

FINANCIAL PERFORMANCE AND LONG-TERM VALUE

In March of 2020, we closed the sale of Emera Maine, which officially completed our asset sale program, a significant accomplishment that strengthened our balance sheet and positions Emera well for future growth.

Emera delivered consolidated financial results that were in line with our annual budget, a reflection of the overall quality of Emera’s business. Emera’s regulated portfolio continued to perform very well, collectively increasing earnings by 13 per cent. This growth underpinned Emera’s adjusted earnings per share (“EPS”) growth and supports the 4 per cent increase in our common share dividend.

We remain focused on providing long-term value to our shareholders. The Management Resources and Compensation Committee’s Letter to Shareholders on page 50 of this Circular provides additional information on our commitments and an overview of our long-term shareholder returns.

ENVIRONMENTAL, SOCIAL AND GOVERNANCE (“ESG”)

Our ESG commitments have been core to our strategy for more than 15 years. In 2020, with oversight from the Board, we took steps to better articulate our ESG commitments along with our approach to governance, risk management and transparency in this important area. We enhanced our ESG disclosures in our annual Sustainability Report with the addition of both the Sustainability Accounting Standards Board and Task Force on Climate-related Financial Disclosures frameworks. We also established executive oversight for ESG and established a Management Sustainability Committee with cross-functional participation that is chaired by the President and CEO.

Decarbonization is a key driver of Emera’s growth and culture of innovation. While we have a strong track record of progress and achievement, we have now also established clear, future-focused carbon reduction goals and our vision to achieve net-zero CO2 emissions by 2050. We announced Emera’s Climate Commitment in February 2021, and more details are included in the Strategy section of this Circular or at www.emera.com/climatecommitment.

 

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Emera’s values are reflected in our commitment to our people, customers and communities. In 2020, through our Community Investment Program, we continued our commitment to helping to build stronger, safer and more innovative communities with $16 million in donations. Together with our employees, we also moved quickly to partner with community leaders to contribute over $6 million to organizations providing critical aid to those most impacted by the COVID-19 pandemic.

We are committed to continuing to build teams and Boards that reflect the communities where we live and work. We’ve made good progress in advancing our multi-year Inclusion and Diversity Strategy, but we recognize we have more work to do. We also recently announced Emera’s Inclusion and Diversity Community Fund, a $5 million fund to support community efforts to remove barriers and advance diversity and inclusion.

SAFETY

Safety is Emera’s number one priority. Last year, in addition to implementing new procedures and protocols to continue to safely deliver for our customers during the pandemic, we also achieved our lowest ever Occupational Safety & Health Association (“OSHA”) and Lost-Time Injury rates. However, two recent contractor fatalities are a reminder that the team must stay relentlessly focused on safety. The team, supported by the Board and its Health, Safety and Environment Committee, is more committed than ever to a strong safety culture and an injury-free Emera.

DIRECTOR CHANGES

We would like to acknowledge Sylvia Chrominska, who is stepping down from the Emera Board this year. Since joining the Board in 2010, Sylvia has been a driving force behind Emera’s human resources strategies and executive compensation practices. As a member of the Management Resources and Compensation Committee (“MRCC”) and serving as Chair of that Committee since 2016, Sylvia’s oversight has been invaluable to the Board and the company. On behalf of the Board and management team, thank you Sylvia. We wish you all the best.

We are also pleased to welcome Karen Sheriff, who joined the Board in February 2021. Karen’s cross-industry executive experience, combined with her expertise in driving innovation, growth and corporate strategy make Karen a strong addition to our Board. On behalf of all of us, welcome Karen.

SHAREHOLDER ENGAGEMENT & ANNUAL SHAREHOLDER MEETING

We value feedback from our shareholders and work hard to provide engagement opportunities, including regular meetings, investor day events and other initiatives.

In 2020, we held an Investor Day on February 25 in Tampa, Florida, one of our last in-person meetings. Despite the limitations on travel and gatherings, our executive team met virtually throughout the year with many shareholders, including all of Emera’s active top 20 investors. Our Annual Meeting of Shareholders is also a valuable opportunity to engage with shareholders on key issues including our annual “Say on Pay” advisory vote on executive compensation.

As the global COVID-19 pandemic continues, and in the interest of public safety, we are providing additional options again this year for remote participation in our Annual Meeting of Shareholders. Our 2021 annual meeting will take place on May 20, at 11:00 a.m. (Atlantic time), at Emera Place, 5151 Terminal Road in Halifax, Nova Scotia. Emera is subject to the Nova Scotia Companies Act annual general meeting requirements, as well as directives under the Nova Scotia Health Protection Act and Emergency Management Act which currently limit the capacity for in-person meetings.

 

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Details on how to participate in the meeting are described in this Circular and will be available prior to the meeting on our website at www.emera.com/investors. Please check the website regularly for updates. Shareholders will be able to participate in the meeting by webcast and will be able to exercise voting rights electronically during the meeting. You will be able to ask questions through the webcast site, or submit questions in advance to AGM@emera.com or in writing at the address provided in this Circular.

We strongly encourage shareholders to take advantage of the option to vote in advance by proxy.

If you have any questions regarding our Annual Meeting of Shareholders, please contact Emera’s Corporate Secretary, Stephen Aftanas, at AGM@emera.com, in writing to P.O. Box 910, Halifax, Nova Scotia B3J 2W5 or by calling 1-800-358-1995 from anywhere in North America or (902) 428-6060 within the Halifax-Dartmouth area.

THANK YOU

We encourage you to review this information and exercise your right to vote at our Annual Meeting of Shareholders. It’s important to us that your views be expressed and that your shares be counted.

Last year highlighted the strength and resiliency of Emera’s team, portfolio and strategy. We are proud of what the Emera team accomplished in 2020. On behalf of the Board and management team, thank you for your ongoing support and confidence in Emera.

 

LOGO    LOGO
Jackie Sheppard    Scott Balfour
Chair of the Board, Emera Inc.    President and CEO, Emera Inc.

 

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NOTICE OF ANNUAL MEETING

 

Thursday, May 20, 2021   Virtual Participation   Emera Place   Record Date
11:00 a.m. Atlantic time  

https://web.lumiagm.

com/429761988

 

5151 Terminal Road

Halifax, Nova Scotia

 

Close of business

March 22, 2021

 

Password: emera2021

 

(case sensitive)

   

 

Items of Business

1.   Electing Directors to serve until the next Annual Meeting of Shareholders;

2.   Appointing Auditors;

3.   Authorizing the Directors to establish the Auditors’ fee;

4.   Considering an advisory resolution on the Company’s approach to executive compensation;

5.   Approving an amendment to the Company’s Senior Management Stock Option Plan; and

6.   Transacting such other business as may properly come before the meeting.

As we respond to the global COVID-19 pandemic, Emera is taking special actions to ensure shareholders have options to participate in the meeting while protecting the safety of shareholders, our team and the community.

Emera is subject to the Nova Scotia Companies Act annual general meeting requirements, as well as directives under the Nova Scotia Health Protection Act and Emergency Management Act regarding social distancing and limits on the size of gatherings.

To address public health concerns and these requirements, Emera will hold its 2021 annual meeting of shareholders with the aid of virtual meeting technology described below.

Registered shareholders and proxyholders will be able to participate in the meeting by webcast and will be able to exercise voting rights electronically during the meeting. Emera encourages all participation in the Meeting to be through the virtual meeting tool that can be found at https://web.lumiagm.com/429761988, using password: emera2021 (case sensitive). Beneficial owners may listen to a live webcast of the meeting through https://web.lumiagm.com/429761988 but will only have the ability to vote virtually or ask questions through the live webcast if they are duly appointed and registered as proxyholders. Inside this Management Information Circular, you will find further details and instructions about virtual participation.

As a shareholder, it is important that you vote. Common shareholders are encouraged to return their proxy or voting instruction form as soon as possible. A postage-paid, pre-addressed envelope is provided. As an alternative, shareholders may choose to vote by telephone or on the internet as provided for on the proxy or voting instruction form. Proxies must be received prior to 5:00 p.m. Atlantic time on Tuesday, May 18, 2021, or if the meeting is adjourned, or postponed, 5:00 p.m. Atlantic time two business days prior to the reconvened meeting date.

Should you have questions or comments, please contact Emera Incorporated by writing to the Corporate Secretary, Emera Incorporated, P.O. Box 910, Halifax, Nova Scotia B3J 2W5 or by calling 1-800-358-1995 from anywhere in North America or (902) 428-6060 within the Halifax-Dartmouth area.

 

LOGO

Stephen D. Aftanas Corporate Secretary

 

4    EMERA INCORPORATED


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MANAGEMENT INFORMATION CIRCULAR

Information as of March 22, 2021 (unless otherwise noted)

MEETING MATERIALS AND NOTICE AND ACCESS

Canadian securities rules (“Notice and Access”) permit Emera Incorporated (the “Company” or “Emera”) to provide you with electronic access to this Management Information Circular (the “Circular”) and the 2020 Annual Report (the “Meeting Materials”) for the Annual Meeting of common shareholders (“shareholders”) instead of sending you a paper copy. Emera is sending Meeting Materials to registered holders and beneficial owners using Notice and Access. This approach is environmentally friendly as it helps reduce paper use. The notice you received includes instructions on how to access and review an electronic copy of the Meeting Materials and how to request a paper copy. The notice also provides instructions on voting by proxy at the meeting. If you would like to receive a paper copy of the Meeting Materials, please follow the instructions in the notice.

For those shareholders who have previously provided instructions to receive paper copies of Meeting Materials, we sent you a paper copy in addition to the notice regarding their electronic availability.

SOLICITATION OF PROXIES

This Circular is furnished in connection with the solicitation of proxies by the Board of Directors of Emera (the “Board of Directors” or “Emera’s Board” or the “Board”) and management of Emera for use at the Annual Meeting (“Meeting”) of Shareholders of the Company to be held on Thursday, May 20, 2021 at 11:00 a.m. (Atlantic time), as set forth in the Notice of Annual Meeting (the “Notice”).

You have received a proxy or voting instruction form. The solicitation of proxies will be primarily by mail although proxies may also be solicited by telephone, facsimile or email, in writing, or in person, by directors of the Company (“Directors”), Officers, or other employees or agents of the Company.

The Company wishes to have as many shareholders vote as possible and has retained D.F. King Canada as the proxy solicitation agent to assist with the solicitation of votes from shareholders. The proxy solicitation agent will monitor the number of shareholders voting and will contact shareholders in order to increase participation in voting. The cost of this solicitation will be borne by the Company and is not expected to exceed $50,000.

RECORD DATE AND VOTING OF SHARES

The date for determining which shareholders are entitled to receive the Notice is Monday, March 22, 2021. This is called the “Record Date”. Only shareholders of record at the close of business on the Record Date will be entitled to vote. Each common share owned as of the Record Date entitles the holder to one vote.

To the knowledge of the Directors and Officers, as of the date of this Circular, no person owned or exercised control over more than 10 per cent of the outstanding common shares of the Company and the only outstanding voting shares were 253,295,950 common shares.

BENEFICIAL (OR NON-REGISTERED) OWNERS

The voting process is different depending on whether you are a registered shareholder, Non-Objecting Beneficial Owner or Objecting Beneficial Owner.

If you have shares registered in your own name, then you are a registered shareholder. If your shares are listed in the name of a nominee, then you are a beneficial or non-registered shareholder. For example, if an account statement is provided to you by a broker, then it is likely that those shares will not be registered in your name, but under the broker’s name or under the name of an agent of the broker such as CDS Clearing and Depository Services Inc., the nominee for many Canadian brokerage firms, or its nominee.

 

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There are two kinds of beneficial owners: (i) Objecting Beneficial Owners – those who object to their name being made known to the issuers of shares which they own and (ii) Non-Objecting Beneficial Owners – those who do not object to their name being made known to the issuers of the shares which they own. Non-Objecting Beneficial Owners will receive a voting instruction form from Emera’s registrar and transfer agent, AST Trust Company (Canada) (“AST”). This is to be completed and returned to AST in the envelope provided. In addition, AST provides both telephone voting and internet voting as described on the voting instruction form.

Securities regulation requires brokers or agents to seek voting instructions from Objecting Beneficial Owners in advance of the Meeting. Objecting Beneficial Owners should be aware that brokers or agents can only vote shares if instructed to do so by the Objecting Beneficial Owner. Your broker or agent (or their agent, Broadridge) will have provided you with a voting instruction form or form of proxy for the purpose of obtaining your voting instructions. Every broker has its own mailing procedures and provides instructions for voting. You must follow those instructions carefully to ensure your shares are voted at the Meeting.

If you are an Objecting Beneficial Owner receiving a voting instruction form or proxy from a broker or agent, you cannot use that proxy to vote in person at the Meeting. To vote your shares at the Meeting, the voting instruction form or proxy must be returned as instructed by the broker well in advance of the Meeting. If you wish to attend and vote your shares in person at the Meeting, follow the instructions for doing so provided by your broker or agent.

VIRTUAL PARTICIPATION

As we continue to respond to the global COVID-19 pandemic, Emera is using virtual meeting technology that will allow participation in the meeting online or by phone. Emera encourages all participation in the meeting to be through the virtual meeting technology that can be found online at https://web.lumiagm.com/429761988, using password: emera2021 (case sensitive). Emera is subject to the Nova Scotia Companies Act annual shareholder meeting requirements, as well as directives under the Nova Scotia Health Protection Act and Emergency Management Act which currently limit the capacity for in-person meetings.

REGISTERED SHAREHOLDERS AND PROXYHOLDERS

Registered shareholders and duly appointed proxyholders may participate virtually in the Meeting using an internet connected device such as a laptop, computer, tablet or mobile phone. A registered shareholder or a proxyholder should simply log in to https://web.lumiagm.com/429761988 and enter their 13-digit Control Number as their username, using the password: emera2021 (case sensitive). If you are a registered shareholder and have appointed a proxyholder to act on your behalf at the Meeting, you must register your proxyholder. Once your proxyholder has been registered, they will receive a Control Number from AST to access the virtual meeting. If you do not register your proxyholder, your proxyholder will not receive a Control Number in order to log in to the Meeting.

Please allow ample time before the start of the Meeting to complete the log-in process. Emera recommends logging in at least 15 minutes prior to the start of the Meeting. In order to be able to vote, please ensure that you are connected to the internet at all times. If you are not connected, your vote may not be recorded. To ensure the optimum experience, virtual participants will need the latest versions of Chrome, Safari, Edge or Firefox (please do not use Internet Explorer). Participants should ensure their browser is compatible by logging in early. Please note that internal network security protocols including firewalls and VPN connections may block access to the virtual meeting technology. If during the meeting, participants experience any difficulty connecting or watching the meeting, they should ensure their VPN setting is disabled or use their computer on a network that is not restricted to security settings of a participant’s organization.

 

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BENEFICIAL (OR NON-REGISTERED) OWNERS

In order to participate online or vote at the meeting, a beneficial or non-registered owner must:

1. appoint themselves as proxyholder;

2. register their proxyholder; and

3. access the meeting as a proxyholder using the Control Number received after registering as a proxyholder.

If you do not register your proxyholder, your proxyholder will not receive a Control Number in order to log in to the meeting. The control number included in any voting instruction form you have received will not enable you to log in to the Meeting.

In order to appoint yourself as a proxyholder, follow the instructions in the form of proxy or voting instruction form sent to you by your intermediary. In most cases, you can simply insert your own name in the form of proxy or voting instruction form, sign it and return it in the envelope provided or you can make the appointment online. Do not complete the voting instructions, as you will be voting at the virtual meeting. However, many Objecting Beneficial Owners located in the United States instead will need to (i) send a request to their intermediary or its agent to send them a legal proxy appointing them as proxyholder and (ii) promptly following receipt of the legal proxy, submit the legal proxy to AST at 1 Toronto Street, Suite 1200, Toronto, Ontario M5C 2V6 prior to 5:00 p.m. Atlantic time on Tuesday, May 18, 2021.

Once a beneficial or non-registered owner has been appointed a proxyholder and has registered as proxyholder, they will receive a Control Number from AST to access the virtual meeting. The beneficial owner should follow the instructions under “Registered Shareholders and Proxyholders” above to log in to the virtual Meeting as a proxyholder.

REGISTERING YOUR PROXYHOLDER

If you are a registered shareholder and wish to appoint a proxyholder to participate virtually in the Meeting or if you are a beneficial or non-registered owner and have appointed yourself as proxyholder, you must contact AST, Emera’s registrar and transfer agent, before 5:00 p.m. (Atlantic time) on Tuesday, May 18, 2021 to obtain a new Control Number to use to access the virtual meeting by:

 

(i)

calling:

1-866-751-6315 (within North America); or

1 (212) 235-5754 (outside of North America); or

 

(ii)

going to AST’s website at https://lp.astfinancial.com/control-number-request-en.html to request the control number by completing an electronic form. This form once completed and submitted online will generate a message to AST to send the Control Number to the designated proxyholder.

SHAREHOLDER PROXY MATERIALS

These security holder materials are being sent to both registered and non-registered owners of the securities. If you are a non-registered owner, and the issuer or its agent has sent these materials directly to you, your name, address and information about your holdings of securities have been obtained in accordance with applicable securities regulatory requirements from the intermediary holding on your behalf. Emera has arranged for its registrar and transfer agent, AST, to send materials directly to Non-Objecting Beneficial Owners. Emera will bear the cost of delivering shareholder proxy materials to registered shareholders, Non-Objecting Beneficial Owners and Objecting Beneficial Owners.

By choosing to send these materials to you directly, Emera (and not the intermediary holding on your behalf) has assumed responsibility for (i) delivering these materials to you as a Non-Objecting Beneficial Owner, and (ii) executing your proper voting instructions. Please return voting instructions as specified in the voting instruction form or form of proxy.

 

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APPOINTMENT AND REVOCATION OF PROXIES

The persons named in the enclosed proxy are Jackie Sheppard, Chair of the Board, Scott Balfour, President and Chief Executive Officer, and Stephen Aftanas, Corporate Secretary of the Company.

For a vote by proxy or voting instruction form to be counted, it must be received prior to 5:00 p.m. (Atlantic time) on Tuesday, May 18, 2021, or if the meeting is adjourned or postponed, by 5:00 p.m. Atlantic time two business days prior to the reconvened meeting date. The Company reserves the right to accept late proxies and to waive the proxy cut-off with or without notice, but is under no obligation to accept or reject a late proxy. For Canadian residents, a postage-paid, pre-addressed envelope is provided for this purpose.

You may vote by proxy or voting instruction form via mail, the internet or telephone. If you are a registered shareholder or a Non- Objecting Beneficial Owner, you may attend the Meeting in person and submit your completed proxy or vote by ballot.

Completion of a proxy gives discretionary authority to the proxyholder to vote as he, she or they see fit in respect of amendments to matters identified in the Notice, and other matters that may properly come before the Meeting or any adjournment or postponement thereof, whether or not the amendment or other matter that comes before the Meeting is, or is not, routine and whether or not the amendment or other matter that comes before the Meeting is contested. Management of the Company is not aware of any amendments or other matters to be presented for action at the Meeting.

If you appoint Ms. Sheppard, Mr. Balfour or Mr. Aftanas as your proxyholder, they will vote, or withhold from voting, in accordance with your directions. If you do not specify how you want your shares voted, they will vote “For” the:

 

   

election of each of the Directors named in this Circular;

 

   

appointment of Ernst & Young LLP as Auditors;

 

   

authorization of the Directors to establish the Auditors’ fee;

 

   

advisory resolution on the Company’s approach to executive compensation; and

 

   

approval to amend the Company’s Senior Management Stock Option Plan.

They will vote in accordance with their best judgment if any other matters are properly brought before the Meeting.

You may appoint any other person (who need not be a shareholder) to represent you at the Meeting by inserting that person’s name in the space provided on the proxy or voting instruction form. That person is your proxyholder and must participate and vote at the Meeting for your vote to count.

You may revoke your proxy by providing new voting instructions in a new proxy or voting instruction form with a later date, or at a later time if you are voting on the internet or by telephone. Any new voting instructions, however, will only take effect if received prior to 5:00 p.m. (Atlantic time) on Tuesday, May 18, 2021, or if the meeting is adjourned or postponed, 5:00 p.m. (Atlantic time) two business days prior to the reconvened meeting date. You may also revoke your proxy without providing new voting instructions by giving written notification addressed to Mr. Stephen Aftanas, Corporate Secretary, P.O. Box 910, Halifax, Nova Scotia B3J 2W5, no later than the last business day preceding the day of the Meeting or preceding the day of any postponement or adjournment thereof or with the Chair of the Meeting on the day of the Meeting or the day of any postponement or adjournment thereof or in any other manner permitted by law. Registered shareholders and Non-Objecting Beneficial Owners may attend the Meeting and vote their shares in person and, if they do so, any voting instructions previously given by such persons for such shares will be revoked.

RESTRICTION ON SHARE OWNERSHIP AND VOTING

Under Nova Scotia legislation, no Emera shareholder may own or control, directly or indirectly, more than 15 per cent of the outstanding voting shares. This restriction may be enforced by limiting non-complying shareholders’ voting rights (including by disqualifying or deeming votes to have not been cast by such non-complying shareholders), dividend rights and transfer rights. Shareholders may be required, at any time, to furnish a statutory declaration to verify the number of shares held to ensure compliance with this restriction.

If you have any questions about the share ownership and voting restriction, please contact the Corporate Secretary using the contact information contained in the Notice.

 

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BUSINESS OF THE MEETING

 

1.

Election of the Board of Directors: The 11 nominees proposed for election as Directors at the 2021 Meeting are identified under Director Nominees in this Circular. For more information about the process for nominating Directors, see Nomination of Directors and Director Recruitment Process in the Statement of Corporate Governance Practices.

All nominees are currently Directors of the Company. Each nominee has indicated his or her willingness to serve as a Director. Each Director elected at the Meeting will hold office until the next Annual Meeting of Shareholders.

Ms. Sheppard, Mr. Balfour and Mr. Aftanas intend to vote proxies received “For” the 11 nominees unless instructed otherwise by shareholders in their proxy.

 

2.

Appointment of Auditors: Emera’s Audit Committee evaluates and recommends to the Board of Directors the external Auditors to be nominated for issuing the Auditors’ reports and performing other audit or review services. Once appointed, the Auditors report directly to the Audit Committee, which oversees its work for the Company. The Audit Committee is responsible for reviewing the experience and qualifications of the Auditors, their performance, their effectiveness and the quality of their service.

Ernst & Young LLP have been Auditors of the Company since its inception in 1998. Ernst & Young have been the Auditors of the Company’s subsidiary, TECO Energy, Inc., since the first quarter of 2018. They were Auditors of the Company’s subsidiary, Nova Scotia Power Inc. (“NSPI”), from 1991 to 2003 and from 2012 to the present.

Every five years, the Committee performs a comprehensive review of the performance of the Auditors over multiple years to provide further insight on the firm, its independence and its application of professional standards. The last comprehensive review occurred in 2017, when the Company initiated a rigorous request for proposals process to provide external audit services to Emera and its subsidiaries. This process was overseen by the Audit Committee, which selected Ernst & Young LLP as the Company Auditors.

The Audit Committee has reviewed the performance of Ernst & Young LLP, including its independence relating to the audit, and recommends the reappointment of Ernst & Young LLP as Auditors.

Ms. Sheppard, Mr. Balfour and Mr. Aftanas intend to vote proxies received “For” the reappointment of Ernst & Young LLP as Auditors of the Company, to hold office until the close of the next Annual Meeting of Shareholders, unless a shareholder specifies their shares be withheld from voting.

 

3.

Auditors’ Fee: The Company is incorporated under the Nova Scotia Companies Act. Shareholder approval of the authorization of Directors to establish the Auditors’ fee is required pursuant to the Companies Act. The aggregate fees billed by Ernst & Young LLP, during the last two fiscal years ended December 31, 2019 and December 31, 2020, were as follows:

 

Service fee    2020 ($)      2019 ($)  

Audit Fees

     1,867,620        2,431,160  

Audit-Related Fees (1)

     19,600        108,000  

Tax Fees (2)

     194,774        311,665  

Total

     2,081,994            2,850,825  

 

  (1)

Audit-Related Fees for Emera relate to fees associated with the audit of pension plans.

 

  (2)

Tax Fees for Emera relate to the structuring of cross-border financing of Emera’s subsidiaries and affiliates as well as tax compliance services and general tax consulting advice on various matters.

Ms. Sheppard, Mr. Balfour and Mr. Aftanas intend to vote proxies received “For” the authorization of Directors to establish the Auditors’ fee, unless a shareholder instructs otherwise in their proxy.

 

4.

Advisory Vote on Executive Compensation: You will be asked to consider and approve, on an advisory basis, a resolution on Emera’s approach to executive compensation as disclosed in this Circular.

Our executive compensation programs are designed to attract, retain, motivate and reward high-calibre leaders to deliver strong performance in alignment with Emera’s corporate strategy and to create and sustain shareholder value. Programs are designed to reflect a blend of short- and long-term incentive plans to reflect our pay-for-performance philosophy and to provide for a significant portion of an executive’s compensation to be at risk, while aligning the structure of programs and payouts with sound risk management and good governance principles.

 

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The Board, through the Management Resources and Compensation Committee (“MRCC”), has directed and reviewed the contents of the Statement of Executive Compensation in this Circular and has unanimously approved it as part of the Committee’s report to you.

As our shareholder, on an advisory basis, you have the opportunity to vote “For” or “Against” our approach to executive compensation through the following resolution:

“RESOLVED, on an advisory basis, and not to diminish the role and responsibilities of the Board of Directors, that the shareholders accept the approach to executive compensation disclosed in the Company’s Management Information Circular delivered in advance of the 2021 Annual Meeting of Shareholders of Emera Incorporated.”

Since your vote is advisory, it will not be binding on the Board; however, the Board, and in particular the MRCC, will seriously consider the outcome of the vote as part of its ongoing review of executive compensation.

Unless otherwise instructed, Ms. Sheppard, Mr. Balfour and Mr. Aftanas intend to vote proxies received “For” the advisory resolution on executive compensation.

 

5.

Senior Management Stock Option Plan Amendment: To consider and, if thought appropriate, to pass an ordinary resolution (the full text of which is reproduced in Appendix “B” of this Circular), ratifying, confirming and approving an increase in the maximum number of common shares reserved for issuance under the Company’s Senior Management Stock Option Plan (the “Plan”) from 11,700,000 to 14,700,000 common shares (an increase of 3,000,000 shares), and any amendments or variations thereto that may come before the Meeting. The Plan is an important part of the Company’s long-term incentive program for senior management. This amendment, if approved, would replenish the inventory of common shares available for issuance under the Plan which would otherwise be exhausted by the Company for the 2022 grants. This increase will allow for a sufficient reserve balance to be maintained, based on granting an average of 550,000 options per year, for the next five years. For more information about this Amendment of the Plan, see Senior Management Stock Option Plan Amendment in the Statement of Corporate Governance Practices later in this Circular.

Unless otherwise instructed, Ms. Sheppard, Mr. Balfour and Mr. Aftanas intend to vote proxies received “For” the amendment of the Company’s Senior Management Stock Option Plan.

DIRECTOR NOMINEES

The following pages set out the names of the nominees proposed for election as Directors of Emera. Biographical information about the Director nominees is also provided, including age, municipality and country of residence, year first elected or appointed as a Director, principal occupation, education, skills and experience. The information about each Director nominee includes Committee memberships and meeting attendance. Their membership on other public company boards in the last five years is also described.

There is information about the common shares and deferred share units (“DSUs”) of Emera held by each Director nominee for the past three years. The estimated value of each Director nominee’s common shares and DSU holdings is based on the following:

 

Year-end    Closing price of Emera common shares ($)  

December 31, 2018

     43.71  

December 31, 2019

     55.79  

December 31, 2020

     54.10  

All Director nominees are required to meet share ownership guidelines. The information below details their status under those guidelines. For further information on the share ownership guidelines for Directors, see Director Share Ownership Guidelines in the Statement of Corporate Governance Practices later in this Circular. For further information on the share ownership guidelines for the Company’s executive officers, including Mr. Balfour, see Executive Share Ownership Requirements and Anti-Hedging Policy in the Statement of Executive Compensation.

All Director nominees, except Mr. Balfour and John Ramil, are considered by the Board to be independent. For more information about the Company’s definition of independence, see Director Independence in the Statement of Corporate Governance Practices later in the Circular.

 

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Skills and Experience Total

 

LOGO

The above bar chart shows eight categories of skills and experience important to the Company’s business and governance (along the vertical axis), and the number of the 11 Director nominees who possess those skills and experience (along the horizontal axis). The details of each Director nominee’s skills and experience are contained in their biographies later in this Circular.

The voting results for those Directors who were nominees for election in the 2020 Annual Meeting of Shareholders are shown in the two rows below.

 

      Scott C.
Balfour
     James V.
Bertram
     Sylvia D.
Chrominska
     Henry E.
Demone
     Kent M.
Harvey
     B. Lynn
Loewen
     John B.
Ramil
     Andrea S.
Rosen
     Richard P.
Sergel
     M. Jackie
Sheppard
     Jochen
E. Tilk
 

Percentage of votes cast “For” each Director (%)

     99.82        99.77        99.76        99.86        99.54        99.86        99.74        99.34        99.75        99.81        99.76  

Percentage of votes cast “Withheld” (%)

     0.18        0.23        0.24        0.14        0.46        0.14        0.26        0.66        0.25        0.19        0.24  

 

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SCOTT BALFOUR

Age: 56

Halifax, Nova Scotia

Canada

Director Since: 2018

Not Independent

Chief Executive Officer of Emera

 

LOGO  

 

Skills and Experience

•  CEO/Senior Executive

•  Customer/Stakeholder

•  M&A/Growth Strategy

•  Governance/Other Directorship

•  Financial

•  Energy Sector

•  Compensation and Human Resources

•  Legal and Regulatory

 

 

 

  

Mr. Balfour was appointed a Director and President and Chief Executive Officer of Emera in 2018.

Mr. Balfour has held executive positions since joining Emera in April 2012, including Chief Operating Officer and Chief Financial Officer. Before joining Emera, he served 17 years in a variety of roles, including President and Chief Financial Officer at Aecon Group Inc., a Canadian publicly traded construction and infrastructure development company.

Mr. Balfour is a Director of many Emera subsidiaries, including being Chair of Tampa Electric Company and Nova Scotia Power Inc. He also serves as Director of the Business Council of Canada. He is a former Director of Martinrea International Inc. and past-Chair of the Ontario Energy Association.

Mr. Balfour received his Master of Business Administration from Richard Ivey School of Business, University of Western Ontario. He earned a Bachelor of Business Administration (Honours) from Wilfrid Laurier University.

Mr. Balfour’s strong financial, operations and public company executive experience provide the foundation for his contribution to the Board and his leadership of Emera. His knowledge of capital markets and his experience in growing a business through the development and execution of strategy as well as through mergers and acquisitions, and then leading teams and structuring systems to manage that growth, are tremendous assets for the Company.

 

Board/Committee membership

 

    

 

Attendance  

 

 

 

    

 

Total  

 

 

 

  

Public company board

membership during the last five

years

•  Board member (1)

     10 of 10          100%       

•  Martinrea International Inc. (June 2013 to June 2020)

 

DSUs awarded and held

2020 share-based   

awards ($)  

  

Total 2020 increase in value of   

all DSUs held ($)  

  

Market value of total DSU   

holdings ($)  

14,264      646,783      4,769,727  

 

Securities held

Year

   Common   shares     DSUs     Value of shares   and DSUs ($)      Status under share ownership guidelines

2020

2019

2018

   55,388   53,004   50,627     88,165   73,901   51,103     7,766,217   7,080,031   4,446,618      As Chief Executive Officer of Emera, Mr. Balfour is subject to Executive Share Ownership Requirements. This requires that he own shares and/or DSUs valued at five times his salary. He exceeds this requirement.

 

(1)

Mr. Balfour attended all committee meetings in 2020 in his capacity as President and Chief Executive Officer.

 

 

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JAMES BERTRAM

Age: 64

Calgary, Alberta

Canada

Director Since: 2018

Independent

 

LOGO  

 

Skills and Experience

•  CEO/Senior Executive

•  Customer/Stakeholder

•  M&A/Growth Strategy

•  Governance/Other Directorship

•  Energy Sector

•  Compensation and Human Resources

 

 

 

  

Mr. Bertram has been a Director since July 2018. He became a member of the Management Resources and Compensation Committee in November 2018. He was appointed Chair of the Health, Safety and Environment Committee in May 2019.

Mr. Bertram is Chair of the Board of Keyera Corp., one of Canada’s leading publicly traded midstream oil and gas operators. He was Chief Executive Officer of Keyera from its inception in 1998 until 2015, when he became Executive Chair. He retired as an officer of Keyera in 2016. He was previously Vice President, Marketing for the worldwide operations of Gulf Canada.

Mr. Bertram is a Director of Methanex Corporation, the world’s largest producer and supplier of methanol to major international markets.

Mr. Bertram received his Bachelor of Commerce from the University of Calgary.

With his experience growing a business and completing major acquisitions, while enabling consistent delivery of value to customers and shareholders, Mr. Bertram makes an important contribution to the Emera Board of Directors.

 

Board/Committee membership

 

    

 

Attendance  

 

 

 

    

 

Total 

 

 

 

  

Public company

board membership during the last five

years

•  Board member

•  Management Resources and Compensation Committee member

•  Health, Safety and Environment Committee Chair

    

10 of 10  

4 of 4  

4 of 4  

 

 

 

    

100% 

100% 

100% 

 

 

 

  

•  Keyera Corp. (2003 to present)

•  Methanex Corporation (October 2018 to present)

 

Total compensation

Fees earned in 2020 ($)      All other compensation ($)      Total ($)  
257,986       Nil      257,986  

 

DSUs awarded and held

2020 share-based   

awards ($)  

  

Total 2020 increase in value   

of all DSUs held ($)  

  

Market value of total DSU  

holdings ($)  

257,986      260,709      692,426  

 

Securities held

Year

  

Common  

shares  

  DSUs    

Value of shares  

and DSUs ($)  

   Status under share ownership guidelines

2020

2019

2018

  

Nil  

Nil  

Nil  

 

12,799  

7,738  

2,434  

 

692,426  

431,717  

106,390  

   Mr. Bertram owns DSUs valued at 91% of the requirement under the Share Ownership guidelines. He has until July 2023 to meet the guidelines.
 

 

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HENRY DEMONE

Age: 66

Lunenburg, Nova Scotia

Canada

Director Since: 2014

Independent

 

LOGO  

 

Skills and Experience

•  CEO/Senior Executive

•  Customer/Stakeholder

•  M&A/Growth Strategy

•  Governance/Other Directorship

•  Compensation and Human Resources

 

 

 

  

Mr. Demone joined the Emera Board of Directors in September 2014. He also became a member of the Management Resources and Compensation Committee at that time. He was appointed to the Nominating and Corporate Governance Committee in May 2017.

He is the former Chairman of High Liner Foods of Lunenburg, Nova Scotia, the leading North American processor and marketer of value-added frozen seafood. He was President of High Liner Foods from 1989 until he became President and Chief Executive Officer from 1992 until May 2015. He was reappointed Chief Executive Officer of High Liner Foods on an interim basis from August 2017 until April 2018.

Mr. Demone is a corporate director, and currently sits on the Board of Saputo Inc., a Montreal-based Canadian dairy company which produces, markets and distributes a wide array of dairy products. He is past-Chair of the Fisheries Council of Canada and The Groundfish Forum, a global trade association representing industry leaders. He has served on the Boards of Dover Industries Ltd. and Maritime Tel & Tel (Aliant). Mr. Demone was also the first non-US citizen to be named Chair of the National Fisheries Institute, a US national trade association.

Mr. Demone received his Bachelor of Science in Mathematics with honours from Acadia University.

In both public and private entities, Mr. Demone has extensive experience in strategic planning, global markets, and mergers and acquisitions. As a long-time business leader in Atlantic Canada, Mr. Demone’s robust business relationships and his solid reputation make him a valuable member of Emera’s Board of Directors.

 

Board/Committee membership

 

    

 

Attendance  

 

 

 

   Total  

 

  

Public company board

membership during the last five

years

•  Board member

•  Nominating and Corporate Governance Committee member

•  Management Resources and Compensation Committee member

    

 

10 of 10  

4 of 4  

 

4 of 4  

 

 

 

 

   100%  

100%  

100%

  

•  Saputo Inc. (2012 to present)

•  High Liner Foods Inc. (1989 to 2019)

 

Total compensation  

Fees earned in 2020 ($)      All other compensation ($)      Total ($)  
250,986      Nil      250,986  

 

DSUs awarded and held

2020 share-based   

awards ($)  

  

Total 2020 increase in value   

of all DSUs held ($)  

  

Market value of total DSU  

holdings ($)  

142,500      160,749      1,589,945  

 

Securities held

Year

   Common   shares     DSUs     Value of shares   and DSUs ($)      Status under share ownership guidelines

2020

2019

2018

   9,062   10,477   10,417     29,389   25,617   19,558     2,080,199   2,013,684   1,310,207      Mr. Demone owns shares and DSUs valued at 275% of the requirement under the Share Ownership guidelines; therefore, the guidelines are met.
 

 

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KENT HARVEY

Age: 62

New York, New York

USA

Director Since: 2017

Independent

 

LOGO  

 

Skills and Experience

•  CEO/Senior Executive

•  Customer/Stakeholder

•  Financial

•  M&A/Growth Strategy

•  Energy Sector

 

 

 

  

Mr. Harvey joined the Emera Board of Directors in November 2017 and was appointed to the Audit Committee at that time. He became Chair of the Audit Committee in June 2020. He has been a member of the Health, Safety and Environment Committee since May 2019.

Mr. Harvey is former Chief Financial Officer for PG&E Corporation, which is headquartered in San Francisco. PG&E Corporation is the parent company of Pacific Gas and Electric Company, one of the largest combined natural gas and electric energy companies in the United States. After 33 years in progressively senior roles, he retired from PG&E Corporation in 2016.

Born in Montreal, Mr. Harvey is a naturalized US citizen. He holds a bachelor’s degree in Economics and a master’s degree in Engineering – Economic Systems, both from Stanford University. He has served as Trustee of the American Conservatory Theater and Director of the North Bay Leadership Council. He works as a crisis services volunteer at the Trevor Project, which focuses on suicide prevention among LGBTQ youth.

Mr. Harvey is an energy industry leader and strategic thinker with strong US experience and financial depth, which are great assets to the Emera Board.

 

Board/Committee membership

 

    

 

Attendance  

 

 

 

    

 

Total  

 

 

 

  

Public company board

membership during the last five

years

•  Board member

•  Audit Committee Chair

•  Health, Safety and Environment Committee member

    

10 of 10  

5 of 5  

4 of 4  

 

 

 

    

100%  

100%  

100%  

 

 

 

   None  

 

Total compensation

Fees earned in 2020 ($)      All other compensation ($)      Total ($)  
301,557       Nil      301,557  

 

DSUs awarded and held

2020 share-based   

awards ($)  

  

Total 2020 increase in value   

of all DSUs held ($)  

   Market value of total DSU   holdings ($)  
142,500      145,449      490,417  

 

Securities held

Year

   Common   shares     DSUs     Value of shares   and DSUs ($)      Status under share ownership guidelines

2020

2019

2018

  

Nil  

Nil  

Nil  

  9,065   6,183   3,129    

490,417  

344,968  

136,768  

  

Mr. Harvey owns DSUs valued at 65% of the requirement under the Share Ownership guidelines. He has until November 2022 to meet the guidelines.

 

 

 

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LYNN LOEWEN, FCPA, FCA

Age: 59

Westmount, Quebec

Canada

Director Since: 2013

Independent

 

LOGO  

 

Skills and Experience

•  CEO/Senior Executive

•  Governance/Other Directorships

•  Customer/Stakeholder

•  Financial

 

 

 

  

Ms. Loewen has been a Director of the Company since February 2013. She has been a member of the Audit Committee since May 2013 and the Health, Safety and Environment Committee since May 2017.

Ms. Loewen is the former President of Minogue Medical Inc., a healthcare organization specializing in the delivery of innovative medical technologies, supplies and equipment to hospitals and medical clinics. She was President of Expertech Network Installation Inc. from 2008 to 2011. She held key positions with Bell Canada Enterprises, as Vice President of Finance Operations from 2005 to 2008, and as Vice President of Financial Controls from 2003 to 2005. Prior to that, she was Vice President of Corporate Services and Chief Financial Officer of Air Canada Jazz, where she held positions of increasing responsibility since 1988.

Ms. Loewen is a Director of Xplornet Communications Inc., a Canadian broadband service provider. She was a member of the Public Sector Pension Investment Board from 2001 to 2007, where she served on the Audit Committee from 2003 to 2007 and as Audit Committee Chair from 2006 to 2007. She was Chair of the Governance Committee from 2003 to 2006.

Ms. Loewen holds a Bachelor of Commerce from Mount Allison University and obtained her Chartered Accountant designation in 1986. She served on the Mount Allison University Board of Regents from 1998 to 2008 and as Chair from 2007 to 2008. In January 2018, she was appointed Chancellor of the University. She also served as a member of the Advisory Board of the Ron Joyce Centre for Business Studies from 2009 to 2011.

Ms. Loewen’s financial expertise and business acumen gained as a senior executive in the telecom and airline sectors are valuable assets for Emera’s Board.

 

Board/Committee membership

     Attendance          Total       

Public company board membership

during the last five years

•  Board member

•  Audit Committee member

•  Health, Safety and Environment Committee member

    

10 of 10  

5 of 5  

4 of 4  

 

 

 

    

100%  

100%  

100%  

 

 

 

   None

 

Total compensation

Fees earned in 2020 ($)      All other compensation ($)      Total ($)  
252,986       Nil       252,986  

 

DSUs awarded and held

2020 share-based   

awards ($)  

  

Total 2020 increase in value   

of all DSUs held ($)  

  

Market value of total DSU  

holdings ($)  

252,986      276,277      2,157,616  

 

Securities held

Year

   Common   shares     DSUs     Value of shares   and DSUs ($)      Status under share ownership guidelines

2020

2019

2018

   4,384   4,193   3,999     39,882   33,722   27,292     2,394,791   2,155,266   1,367,730      Ms. Loewen owns shares and DSUs valued at 316% of the requirement under the Share Ownership guidelines; therefore, the guidelines are met.
 

 

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JOHN RAMIL

Age: 65

Tampa, Florida

USA

Director Since: 2016

Not Independent

Former President and Chief Executive

Officer of TECO Energy, Inc. (1)

 

LOGO  

 

Skills and Experience

•  CEO/Senior Executive

•  M&A/Growth Strategy

•  Energy Sector

•  Customer/Stakeholder

•  Financial

•  Legal and Regulatory

 

 

 

  

Mr. Ramil has been a Director since September 2016 and a member of the Health, Safety and Environment Committee since May 2017. He is the former President and Chief Executive Officer of TECO Energy, Inc. (“TECO”), having retired as President and Chief Executive Officer of TECO on August 31, 2016 after Emera acquired TECO on July 1, 2016.

Mr. Ramil had a distinguished 40-year career with TECO which included becoming TECO’s President in 2004. He joined the TECO Board of Directors in 2008 and became Chief Executive Officer in 2010.

Mr. Ramil is Chair of the Boards of GuideWell Mutual Holding Corporation and Blue Cross and Blue Shield of Florida. He also serves on the Board of Directors of the Moffitt Cancer Center Institute and is a member of the Florida Council of 100.

Mr. Ramil is Trustee and past-Chair of the University of South Florida. He is a former member of the Board of the Edison Electric Institute, an industry association, and is a former member of the Board of Tampa Bay Partnership. Previously, he served as Chairman of the Greater Tampa Chamber of Commerce and the Tampa Hillsborough Economic Development Corp. He was also a member of the Boards of the Southeastern Electric Exchange and the Florida Electric Power Coordinating Group.

Mr. Ramil received his Bachelor of Science, Master of Science and Honorary Doctorate in Engineering from the University of South Florida (“USF”). In 1999, he was named USF’s Distinguished Alumnus and is the longest-serving member of the USF Board of Trustees, serving as its Chairman from 2010 to 2015.

Mr. Ramil brings significant business and utility sector experience to Emera’s Board, as well as a deep understanding and involvement in his community. His range and depth of skills are a great asset for Emera.

 

Board/Committee membership

 

    

 

Attendance  

 

 

 

    

 

Total  

 

 

 

  

Public company board

membership during the last five years

•  Board member

•  Health, Safety and Environment Committee member

    

10 of 10  

4 of 4  

 

 

    

100%  

100%  

 

 

  

•  TECO Energy, Inc. (August 2010 to August 2016)

 

Total compensation

Fees earned in 2020 ($)      All other compensation ($)      Total ($)  
273,673      Nil       273,673  

 

DSUs awarded and held

2020 share-based   

awards ($)  

  

Total 2020 increase in value   

of all DSUs held ($)  

  

Market value of total DSU  

holdings ($)  

273,673      285,269      1,352,230  

 

Securities held

Year

   Common   shares     DSUs     Value of shares   and DSUs ($)      Status under share ownership guidelines

2020

2019

2018

  

Nil  

Nil  

Nil  

  24,995   19,125   12,703     1,352,230   1,066,961   555,248      Mr. Ramil owns DSUs valued at 179% of the requirement under the Share Ownership guidelines; therefore, the guidelines are met.

 

(1)

Mr. Ramil’s independence is a matter for the determination of the Board of Directors of Emera as to whether he has a direct or indirect material relationship with Emera. As he retired as the President and CEO of TECO on August 31, 2016, the Board has determined that he should not be considered independent at this time. This determination is subject to review by the Emera Board in September 2021, and Mr. Ramil’s status in this regard may change based on the Board’s review and further determination at that time.

 

 

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ANDREA ROSEN

Age: 66

Toronto, Ontario

Canada

Director Since: 2007

Independent

 

LOGO  

 

Skills and Experience

•  CEO/Senior Executive

•  M&A/Growth Strategy

•  Governance/Other Directorships

•  Financial

 

 

 

 

 

  

Ms. Rosen has been a Director since January 2007 and became a member of Emera’s Audit Committee in May of the same year. She served as Audit Committee Chair from April 2008 to June 2020. She was appointed to the Nominating and Corporate Governance Committee in May 2019 and was appointed Chair of that Committee in June 2020.

Ms. Rosen was a member of the two ad hoc Committees formed by the Board in August 2015 and November 2016 to oversee certain aspects of the financing related to the TECO transaction and the equity offering completed in December 2016. She was also appointed to the ad hoc Committee formed by the Board in November 2017 to oversee the equity offering completed in December 2017.

Ms. Rosen was Vice Chair of TD Bank Financial Group and President of TD Canada Trust from 2002 to 2005. Prior to this, she was Executive Vice President of TD Commercial Banking and Vice Chair of TD Securities. From 1991 to 1994, Ms. Rosen also served as Vice President of Varity Corporation. Between 1981 and 1990, she held a variety of roles at Wood Gundy Inc. (later CIBC Wood Gundy), eventually becoming Vice President and Director.

Ms. Rosen is a corporate director. She is a Director of Manulife Financial Corporation, a Canadian multinational insurance company and financial services provider. She is also a Director on the Boards of Ceridian HCM Holding Inc., a global human capital management software company, and Element Fleet Management Corp., a global fleet management company providing services and financing for commercial vehicle fleets. She is a former Director of Alberta Investment Management Corporation (“AIMCo”) and Hiscox Ltd. She is also a member of the Board of Directors of the Institute of Corporate Directors.

Ms. Rosen received her Bachelor of Laws degree from Osgoode Hall Law School and a Master of Business Administration from the Schulich School of Business at York University. She earned a Bachelor of Arts degree from Yale University.

Ms. Rosen has spent over 20 years in the corporate finance field and is an experienced senior executive. Her career in the investment and commercial banking industry has given her extensive financial and investment knowledge. Her expertise is of significant value to Emera.

 

Board/Committee membership

 

    

 

Attendance  

 

 

 

    

 

Total  

 

 

 

  

Public company board

membership during the last five

years

•  Board member

•  Audit Committee member

•  Nominating and Corporate Governance Committee Chair

    

10 of 10  

5 of 5  

4 of 4  

 

 

 

    

100%  

100%  

100%  

 

 

 

  

•  Element Fleet Management Corp. (May 2019 to present)

•  Ceridian HCM Holding Inc. (July 2018 to present)

•  Manulife Financial Corporation (August 2011 to present)

 

Total compensation

Fees earned in 2020 ($)      All other compensation ($)      Total ($)  
263,418      Nil       263,418  

 

DSUs awarded and held

2020 share-based   

awards ($)  

  

Total 2020 increase in value   

of all DSUs held ($)  

  

Market value of total DSU  

holdings ($)  

263,418      313,296      4,087,742  

 

Securities held

Year

   Common   shares     DSUs     Value of shares   and DSUs ($)      Status under share ownership guidelines

2020

2019

2018

   14,336   14,336   14,336     75,559   67,655   59,325     4,863,320   4,574,251   3,219,722      Ms. Rosen owns shares and DSUs valued at 642% of the requirement under the Share Ownership guidelines; therefore, the guidelines are met.
 

 

18    EMERA INCORPORATED


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NOTICE OF ANNUAL MEETING OF COMMON SHAREHOLDERS AND MANAGEMENT INFORMATION CIRCULAR

 

RICHARD SERGEL

Age: 71

Boston, Massachusetts

USA

Director Since: 2010

Independent

 

LOGO  

 

Skills and Experience

•  CEO/Senior Executive

•  Customer/Stakeholder

•  M&A/Growth Strategy

•  Governance/Other Directorship

•  Financial

•  Energy Sector

•  Compensation and Human Resources

•  Legal and Regulatory

 

 

 

  

Mr. Sergel has been a Director since September 2010. He has been a member of the Nominating and Corporate Governance Committee since November 2010 and was reappointed to the Audit Committee in May 2019 after first serving on this committee from 2010 to 2014.

Mr. Sergel was a member of the Management Resources and Compensation Committee from September 2014 to May 2019 and a member of the ad hoc Pension Governance Committee from November 2013 to May 2014. He was a member of the two ad hoc Committees formed by the Board in August 2015 and November 2016 to oversee certain aspects of the financing related to the TECO transaction and the equity offering completed in December 2016. He was also appointed to the ad hoc Committee formed by the Board in November 2017 to oversee the equity offering completed in December 2017.

Mr. Sergel is also a Director of the Company’s subsidiary, Emera US Holdings Inc.

Mr. Sergel is the former President and Chief Executive Officer of the North American Electric Reliability Corporation (“NERC”), a regulatory authority for the bulk electricity system in North America. Before that he served as President and Chief Executive Officer of National Grid USA, and its predecessor, New England Electric System, from 1998 to 2004.

Mr. Sergel is a corporate director and is a Director of State Street Corporation. He previously served on the Boards of the Edison Electric Institute and the United Way of the Merrimac Valley. He was also Chairman of the Consortium for Energy Efficiency.

Mr. Sergel holds a Bachelor of Science in Mathematics from Florida State University, a Master of Science in Applied Mathematics from North Carolina State University and a Master of Business Administration from the University of Miami.

Mr. Sergel’s extensive career in the US electricity sector has provided him with valuable industry and business skills and experience which along with his regulatory background is a distinct asset to Emera.

 

Board/Committee membership

 

    

 

Attendance  

 

 

 

    

 

Total  

 

 

 

  

Public company board

membership during the last five

years

•  Board member

•  Nominating and Corporate Governance Committee member

•  Audit Committee member

 

    

 

10 of 10  

4of 4  

 

5 of 5  

 

 

 

 

    

 

100%  

100%  

 

100%  

 

 

 

 

  

•  State Street Corporation (September 1999 to present)

 

Total compensation

Fees earned in 2020 ($)      All other compensation ($)      Total ($)  
290,361      13,351      303,712  

 

DSUs awarded and held

2020 share-based   

awards ($)  

  

Total 2020 increase in value   

of all DSUs held ($)  

  

Market value of total DSU  

holdings ($)  

142,500      156,880      1,311,059  

 

Securities held

Year

   Common   shares     DSUs     Value of shares   and DSUs ($)      Status under share ownership guidelines

2020

2019

2018

   8,500   8,500   5,500     24,234   20,688   16,986     1,770,909   1,628,394   982,863      Mr. Sergel owns shares and DSUs valued at 234% of the requirement under the Share Ownership guidelines; therefore, the guidelines are met.
 

 

EMERA INCORPORATED    19


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NOTICE OF ANNUAL MEETING OF COMMON SHAREHOLDERS AND MANAGEMENT INFORMATION CIRCULAR

 

 

JACKIE SHEPPARD

Age: 65

Calgary, Alberta

Canada

Director Since: 2009

Independent

 

LOGO  

 

Skills and Experience

•  CEO/Senior Executive

•  Customer/Stakeholder

•  M&A/Growth Strategy

•  Governance/Other Directorship

•  Financial

•  Energy Sector

•  Compensation and Human Resources

•  Legal and Regulatory

 

 

 

 

  

Ms. Sheppard has been an Emera Director since February 2009 and became Chair of the Board in May 2014.

She was a member of the Management Resources and Compensation Committee from May 2009 to May 2014, and the Audit Committee from May 2009 to October 2014. She was Chair of the two ad hoc Committees formed by the Board in August 2015 and November 2016 to oversee certain aspects of the financing related to the TECO transaction and the equity offering completed in December 2016. She was also Chair of the ad hoc Committee formed by the Board in November 2017 to oversee the equity offering completed in December 2017.

Ms. Sheppard was a Director of the Company’s subsidiary Emera Newfoundland & Labrador Holdings Inc. from 2011 until May 2016.

Ms. Sheppard is the former Executive Vice President, Corporate and Legal of Talisman Energy Inc. She is a Director on the Boards of Seven Generations Energy Ltd., a publicly traded energy company focused on Canadian natural gas development, as well as Alberta Investment Management Corporation (“AIMCo”), an institutional investment manager. She is founder and Lead Director of Black Swan Energy Inc., an Alberta upstream energy company that is private equity financed. She is a former Director of Cairn Energy PLC, a publicly traded UK-based international upstream company, and she served as Chair of the Research and Development Corporation of the Province of Newfoundland and Labrador, a provincial Crown corporation, until June 2014.

Ms. Sheppard is a Rhodes Scholar, having received an Honours Jurisprudence, Bachelor of Arts and Master of Arts from Oxford University in 1979. She earned a Bachelor of Laws degree (Honours) from McGill University in 1981 and a Bachelor of Arts degree from Memorial University of Newfoundland in 1977. She was awarded an honorary Doctor of Laws degree from Memorial University in 2019.

With her extensive roles as an executive in the energy industry, and as a director of public, private and Crown corporations, Ms. Sheppard’s experience in strategic planning, business development, public markets, legal and governance are the foundation for her leadership of the Board.

 

Board/Committee membership

 

    

 

Attendance  

 

 

 

    

 

Total  

 

 

 

  

Public company board

membership during the last five

years

•  Board Chair (1)

     10 of 10          100%       

•  Seven Generations Energy Ltd. (May 2016 to present)

•  Cairn Energy PLC (May 2010 to December 2018)

 

 

Total compensation

Fees earned in 2020 ($)      All other compensation ($)      Total ($)  
425,000      Nil      425,000  

 

DSUs awarded and held

2020 share-based   

awards ($)  

  

Total 2020 increase in value   

of all DSUs held ($)  

  

Market value of total DSU  

holdings ($)  

425,000      481,245      4,872,246  

 

Securities held

Year

   Common   shares     DSUs     Value of shares   and DSUs ($)      Status under share ownership guidelines

2020

2019

2018

  

11,947  

11,947  

11,947  

 

90,060  

78,706  

66,301  

 

5,518,579  

5,057,524  

3,420,220  

   Ms. Sheppard owns shares and DSUs valued at 729% of the requirement under the Share Ownership guidelines; therefore, the guidelines are met.

 

(1)

Ms. Sheppard attended all Committee meetings in 2020 in her capacity as Board Chair.

 

 

20    EMERA INCORPORATED


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NOTICE OF ANNUAL MEETING OF COMMON SHAREHOLDERS AND MANAGEMENT INFORMATION CIRCULAR

 

 

KAREN SHERIFF

Age: 63

Toronto, Ontario

Canada

Director Since: 2021

Independent

 

LOGO  

 

Skills and Experience

•  CEO/Senior Executive

 

•  Compensation and Human Resources

 

•  Customer/Stakeholder

 

•  M&A/Growth Strategy

 

•  Governance/Other Directorship

 

•  Financial

 

•  Legal and Regulatory

 

 

 

  

Ms. Sheriff has been a Director since February 12, 2021.

Ms. Sheriff is past President and CEO of Q9 Networks Inc., a data centre services provider. Prior to her role at Q9, she served as President and CEO of Bell Aliant, Inc., a telecommunications company, from 2008 to 2014. She was in senior leadership positions for more than nine years with BCE Inc. and currently serves on the BCE Inc. Board of Directors. She also spent over 10 years at United Airlines in the areas of marketing, strategy, human resources and finance.

Ms. Sheriff is currently a Director of CPP Investments Board and is a past Director of WestJet Airlines Ltd.

Ms. Sheriff received her master’s degree in business administration with concentrations in marketing and finance from the University of Chicago. She was named one of Canada’s top 25 Women of Influence for 2013 and 2014 by Women of Influence Inc. She was named Woman of the Year by Canadian Women in Communications and has been recognized as one of Atlantic Canada’s Top 50 CEOs by Atlantic Business Magazine and one of Canada’s Top 100 Most Powerful Women on multiple occasions.

With her extensive senior executive experience including CEO of a public company, and leading role in transforming Bell Aliant, Ms. Sheriff brings 20 years of technology-based industry experience. She brings to Emera valuable experience leading a regulated utility along with her involvement in the sale and acquisition of major business units, including Bell Aliant, Q9, CTV and the sale of WestJet to Onex.

 

Board/Committee membership

 

    

 

Attendance  

 

 

 

     Total       

Public company board

membership during the last five

years

•  Board member (1)

     N/A        N/A     

•  BCE Inc. (2017 to present)

•  WestJet Airlines Ltd. (2016–2019)

 

 

 

Total compensation

Fees earned in 2020 ($)      All other compensation ($)      Total ($)  
Nil      Nil      Nil  

 

DSUs awarded and held

2020 share-based   

awards ($)  

  

Total 2020 increase in value   

of all DSUs held ($)  

  

Market value of total DSU  

holdings ($)  

Nil      Nil      Nil  

 

Securities held

Year

   Common   shares     DSUs     Value of shares   and DSUs ($)      Status under share ownership guidelines

Nil

   Nil     Nil     Nil      Ms. Sheriff has until February 2026 to meet the guidelines.

 

(1)

Ms. Sheriff was appointed a Director in February 2021.

 

 

EMERA INCORPORATED    21


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NOTICE OF ANNUAL MEETING OF COMMON SHAREHOLDERS AND MANAGEMENT INFORMATION CIRCULAR

 

 

JOCHEN TILK

Age: 57

Toronto, Ontario

Canada

Director Since: 2018

Independent

 

LOGO  

 

Skills and Experience

•  CEO/Senior Executive

•  Compensation and Human Resources

•  Customer/Stakeholder

•  M&A/Growth Strategy

•  Governance/Other Directorship

•  Financial

 

 

 

  

Mr. Tilk has been a Director since July 2018 and became a member of the Audit Committee in November of the same year. He was appointed to the Management Resources and Compensation Committee in May 2019.

Mr. Tilk is the former Executive Chair of Nutrien Inc., a Canadian global supplier of agricultural products and services based in Saskatoon, Saskatchewan. He is the former President and Chief Executive Officer of Potash Corporation of Saskatchewan. Previously, Mr. Tilk spent 25 years with Inmet Mining Corporation, a Canadian-based, international metals company, with five of those years as the company’s President and Chief Executive Officer.

Mr. Tilk is a Director of AngloGold Ashanti Limited, a publicly listed international gold mining company headquartered in Johannesburg, South Africa. He is also a Director of the Princess Margaret Cancer Foundation, a not-for-profit organization. He is the former Chair of the Board of Directors of Canpotex Limited and a former Director of the Fertilizer Institute and the International Fertilizer Association.

He received his master’s in mining engineering from Rheinisch-Westfälische Technische Hochschule, a research university located in Aachen, North Rhine-Westphalia, Germany.

Mr. Tilk’s record of growing companies and leading multi-billion-dollar capital expenditure programs makes him an important contributor to Emera.

 

Board/Committee membership

 

    

 

Attendance  

 

 

 

    

 

Total  

 

 

 

  

Public company board

membership during the last five

years

•  Board member

•  Audit Committee member

•  Management Resources and Compensation Committee member

    

10 of 10  

5 of 5  

4 of 4  

 

 

 

    

100%  

100%  

100%  

 

 

 

  

•  AngloGold Ashanti Limited (January 2019 to present)

•  Nutrien Ltd., formerly Potash Corp. (2014 to 2018)

 

Total compensation

Fees earned in 2020 ($)      All other compensation ($)      Total ($)  
252,986      Nil       252,986  

 

DSUs awarded and held

2020 share-based   

awards ($)  

  

Total 2020 increase in value   

of all DSUs held ($)  

  

Market value of total DSU  

holdings ($)  

252,986      254,322      582,928  

 

Securities held

Year

   Common   shares     DSUs     Value of shares   and DSUs ($)      Status under share ownership guidelines

2020

2019

2018

  

Nil  

Nil  

Nil  

  10,775   5,890   1,811     582,928   328,606   79,158      Mr. Tilk owns DSUs valued at 77% of the requirement under the Share Ownership guidelines. He has until July 2023 to meet the guidelines.
 

 

22    EMERA INCORPORATED


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COMPENSATION OF DIRECTORS IN 2020

PURPOSE OF DIRECTOR COMPENSATION

The compensation of Directors is designed to:

 

  a.

attract and retain highly skilled and experienced individuals to serve on Emera’s Board of Directors;

  b.

ensure alignment with shareholders’ long-term interests; and

  c.

recognize the substantial time commitment required to oversee management of the Company.

For more information about the process of determining Director compensation, see Director Compensation in the Statement of Corporate Governance Practices later in the Circular.

DEFERRED SHARE UNITS

In 2020, the annual retainer for each Director was $227,500, of which $142,500 was payable in deferred share units or “DSUs” and the balance was payable in cash. Directors can elect to receive some or all of their cash compensation in the form of additional DSUs. More information about the Directors’ DSU Plan is provided later in this section of the Circular. The Company does not offer option-based awards, non-equity incentive plan participation, or participation in a Company pension plan to its non-executive Directors.

BOARD CHAIR’S ALL-INCLUSIVE RETAINER

The annual Chair’s retainer is an all-inclusive fee, meaning the Board Chair receives no meeting fees or any other retainer for serving as Emera’s Board Chair. The all-inclusive annual retainer of the Board Chair in 2020 was $425,000. This was comprised of $212,500 in DSUs, and the remainder in cash.

COMPENSATION RATES FOR DIRECTORS

Listed below are the annual compensation rates for non-executive Directors. Mr. Balfour does not receive director compensation because he is compensated in the role of President and CEO.

 

Annual retainers for Directors in 2020    Cash amount ($)      DSUs ($)      Total ($)  

Annual Chair’s retainer

     212,500        212,500        425,000    

Annual Director’s retainer

     85,000        142,500        227,500    

Annual Audit Committee Chair’s retainer

     27,500        N/A        27,500    

Annual Audit Committee member’s retainer

     12,500        N/A        12,500    

Annual Management Resources and Compensation Committee Chair’s retainer

     22,500        N/A        22,500    

Annual Management Resources and Compensation Committee member’s retainer

     10,500        N/A        10,500    

Annual Nominating and Corporate Governance Committee Chair’s retainer

     17,500        N/A        17,500    

Annual Nominating and Corporate Governance Committee member’s retainer

     10,500        N/A        10,500    

Annual Health, Safety and Environment Committee Chair’s retainer

     17,500        N/A        17,500    

Annual Health, Safety and Environment Committee member’s retainer

     10,500        N/A        10,500    

Each Director is entitled to an annual travel allowance of $10,000. See Compensation in the Statement of Corporate Governance Practices for a description of how the travel allowance was impacted by the COVID-19 pandemic.

Members of ad hoc committees receive meeting fees ($1,750 in-person meeting fee; $1,250 videoconference/telephone meeting fee) for their participation in each committee meeting, but typically receive no annual retainer for being a member of an ad hoc committee because of the nature of the committee’s existence, having generally been established for a specific purpose and a temporary period of time. For further information on the Company’s committees, see Committees of the Board of Directors in the Statement of Corporate Governance Practices later in this Circular.

 

EMERA INCORPORATED    23


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TOTAL DIRECTOR COMPENSATION IN 2020

The following table sets out the total compensation earned by the Directors who served on Emera’s Board during 2020. Compensation is made up of applicable retainers and the annual $10,000 travel allowance (the travel allowance was determined to be payable to Directors in the first quarter of 2020, but not after as a result of Directors not travelling due to the COVID-19 pandemic – see Director Compensation for more detail).

Mr. Balfour is not included in the table as his compensation for service as Emera’s President and CEO is disclosed in the Statement of Executive Compensation. He does not receive any additional compensation for his services as a member of the Board of Emera or as a member of the Board of any of Emera’s subsidiaries or investments.

In the table below, the columns under the headings “DSUs Awarded” and “DSUs Held” show detailed information about DSUs received by Directors as compensation.

Total Compensation

 

                                   

DSUs

awarded

           

DSUs

held

 
Director     

Fees earned    

in 2020 ($) (1)

 

 

   

All other   
compensation   

($)   

 

 

     Total ($)       

2020
Share-based
awards ($)
 
 
 (2) 
   

Value of DSUs
vested during
2020 ($) (3)
 
 
    

Change in value
of DSUs held

in 2020 ($) (4)

 
 

   

Market value    
of total DSU    

holdings ($) (5)

 
 

 

James Bertram

     257,986          N/A        257,986          257,986       273,807          (13,077 )        692,426     

Sylvia Chrominska

     252,486          N/A        252,486          197,493       292,947          (66,892 )        2,434,288     

Henry Demone

     250,986          N/A        250,986          142,500       204,040          (43,293 )        1,589,945     

Kent Harvey (6)

     301,557          N/A        301,557          142,500       155,898          (10,449 )        490,417     

Lynn Loewen

     252,986          N/A        252,986          252,986       333,241          (56,990 )        2,157,616     

Donald Pether (7)

     113,889          N/A        113,889          113,889       233,344          (94,221 )        1,634,036     

John Ramil (6)

     273,673          N/A        273,673          273,673       317,577          (32,321 )        1,352,230     

Andrea Rosen

     263,418          N/A        263,418          263,418       427,633          (114,337 )        4,087,742     

Richard Sergel (6)

     290,361          13,351(8)        303,712          142,500       191,829          (34,963 )        1,311,059     

Jackie Sheppard

     425,000          N/A        425,000          425,000       614,246          (133,013 )        4,872,246     

Jochen Tilk

     252,986          N/A        252,986          252,986       264,296          (9,954 )        582,928     

 

(1)

The “Fees earned in 2020” column is the amount of Directors’ fees, and includes the dollar value of that portion of their retainer paid in DSUs. All fees are in Canadian dollars.

 

(2)

This column shows the portion of Directors’ fees earned in 2020 that was allocated to DSUs. DSUs granted in 2019 are based on the value of the Emera common share closing price on December 31, 2019 ($55.79).

 

(3)

This column shows the value of all DSUs received in 2020, including received as dividend equivalents during the year, multiplied by the December 31, 2020 Emera common share closing price of $54.10.

 

(4)

This column shows the change in value of all DSUs held by each Director at the beginning of the year because of the change to the Emera common share closing price from $55.79 at the beginning of the year to $54.10 on December 31, 2020.

 

(5)

This column shows the value of all DSUs held by each Director at the end of 2020 based on the December 31, 2020 Emera common share closing price of $54.10.

 

(6)

As US-domiciled Directors, the annual cash retainer, committee retainers, and the associated meeting and travel fees are paid to Mr. Harvey, Mr. Ramil and Mr. Sergel in US dollars, using a one-to-one conversion rate to the Canadian dollar.

 

(7)

Mr. Pether retired from the Board on June 5, 2020. He redeemed 29,861 DSUs on October 2, 2020, leaving a balance of 30,204 DSUs as of December 31, 2020.

 

(8)

Mr. Sergel also received compensation for serving as a Director of Emera US Holdings Inc.

The table above includes compensation earned by Emera Directors who served on the Board of Directors of Emera subsidiaries. What follows is more information about Emera’s Directors who served on the Boards of its subsidiaries.

 

24    EMERA INCORPORATED


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COMPENSATION OF EMERA DIRECTORS ON SUBSIDIARY BOARDS

The Emera Board of Directors, on the recommendation of the Nominating and Corporate Governance Committee, determines the compensation to be received by Emera Directors who serve on the Boards of Emera’s subsidiaries. Such compensation received by each Emera Director that serves as a Director on the Board of an Emera subsidiary is reported under “All other compensation” and “Total” in the Total Compensation table on the previous page.

Mr. Sergel was a member of the Board of Directors of Emera US Holdings Inc., a US holding company which is a direct subsidiary of Emera and holds certain US-based investments of Emera. He receives an annual retainer of $10,000 USD for serving on the Emera US Holdings Inc. Board, plus $1,000 USD for any Board meetings.

DIRECTORS’ SHARE OWNERSHIP GUIDELINES

To align the interests of Directors and shareholders, the Directors are subject to share ownership guidelines that require them to own common shares and/or DSUs with a value of not less than three times the annual Director’s retainer within five years following their appointment date or within five years of any change to the Directors’ compensation, whichever is the later date. For the status of each Director nominee under the Director Share Ownership Guidelines, see their biographies earlier in this Circular. For more information about the Director Share Ownership Guidelines, see Director Share Ownership Guidelines in the Statement of Corporate Governance Practices.

DIRECTORS’ DSU PLAN

Under the Directors’ Deferred Share Unit Plan (the “Directors’ DSU Plan”), non-employee Directors may elect to receive all or any portion of their cash compensation in DSUs in lieu of that cash compensation, subject to the requirement to receive a minimum portion of their annual retainer in DSUs.

Directors’ fees are paid on a quarterly basis and, at the time of each quarterly payment, the applicable amount is converted to DSUs. The number of DSUs to be credited is determined by dividing (a) the quarterly portion of the Director’s annual fee that the Director is required to receive in DSUs, together with the portion the Director elected to be paid in DSUs by (b) the fair market value of an Emera common share on the last trading day of the preceding calendar year, with fractions computed to three decimal places.

A DSU is a unit that has a value based upon the value of one Emera common share. When a dividend is paid on Emera’s common shares, the Director’s DSU account is credited with additional DSUs computed by dividing: (a) the amount obtained by multiplying the amount of the dividend declared and paid per common share by the number of DSUs recorded in the Director’s account on the record date for the payment of such dividend by (b) the market price of a common share as of the dividend payment date.

DSUs cannot be redeemed for cash until the Director leaves the Board. The cash redemption value of a DSU equals the market value of a common share at the time of redemption. DSUs are not shares, cannot be converted to shares and do not carry voting rights. DSUs received by Directors in lieu of cash compensation and held by them represent an at-risk investment in Emera. The value of DSUs is based on the value of the common shares of Emera, and therefore is not guaranteed. See Director Compensation in the Statement of Corporate Governance Practices in this Circular for more information about the compensation of Directors. Non-employee Directors are not entitled to participate in any other compensation plan of the Company or in Emera’s Employee Common Share Purchase Plan.

 

EMERA INCORPORATED    25


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NOTICE OF ANNUAL MEETING OF COMMON SHAREHOLDERS AND MANAGEMENT INFORMATION CIRCULAR

 

COMMITTEES OF THE BOARD OF DIRECTORS

The Board of Directors has four standing Committees to assist it in carrying out its duties. They are the:

 

   

Audit Committee;

 

   

Management Resources and Compensation Committee (“MRCC”);

 

   

Nominating and Corporate Governance Committee (“NCGC”); and

 

   

Health, Safety and Environment Committee (“HSEC”).

From time to time the Board may establish ad hoc committees to assist the Board on specific matters of a temporary nature.

CERTAIN PROCEEDINGS

To the knowledge of the Company, none of the proposed nominees for election as Directors of the Company:

 

  (a)

are, as at the date of this Circular, or have been, within 10 years before the date of this Circular, a director, chief executive officer or chief financial officer of any company that:

 

  (i)

was subject to a cease trade order, an order similar to a cease trade order or an order that denied the relevant company access to any exemption under securities legislation that was in effect for a period of more than 30 consecutive days (an “Order”) that was issued while the proposed nominee was acting in the capacity as director, chief executive officer or chief financial officer; or

 

  (ii)

was subject to an Order that was issued after the proposed nominee ceased to be a director, chief executive officer or chief financial officer and which resulted from an event that occurred while that person was acting in the capacity as director, chief executive officer or chief financial officer;

 

  (b)

are, as at the date of this Circular, or have been within 10 years before the date of this Circular, a director or executive officer of a company that, while that person was acting in that capacity, or within a year of that person ceasing to act in that capacity, became bankrupt, made a proposal under any legislation relating to bankruptcy or insolvency or was subject to or instituted any proceedings, arrangements or compromise with creditors or had a receiver, receiver manager or trustee appointed to hold its assets; or

 

  (c)

have, within the 10 years before the date of this Circular, become bankrupt, made a proposal under any legislation relating to bankruptcy or insolvency, or become subject to or instituted any proceedings, arrangement or compromise with creditors, or had a receiver, receiver manager or trustee appointed to hold the assets of the proposed nominee.

 

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STATEMENT OF CORPORATE GOVERNANCE PRACTICES

 

 
Corporate governance at a glance
 
Emera’s Board of Directors annually reviews its approach to corporate governance. It monitors best practices of leading corporations with a view to enhancing governance to create and preserve long-term shareholder value. Details of Emera’s corporate governance practices may be found in this Statement of Corporate Governance Practices.
   
Governance highlights   For details see
   

All Emera Directors are independent from management except the President and Chief Executive Officer and John Ramil. Mr. Ramil joined the Board following the closing of Emera’s acquisition of TECO, where he previously held the position of President and CEO.

 

Board of Directors

Page 28

   

The Board oversees the Company’s strategy, which includes reviewing the strategic planning process and annually approving the strategic plan after considering, among other things, the opportunities and risks of the business.

 

Board of Directors

Page 28

   

The Board and, on certain matters by delegation, its Committees oversee the Company’s risk management.

 

Board of Directors

Page 28

   

The Charter of the Chair of the Board of Directors and position descriptions for each of the Committee Chairs describe the roles and responsibilities for these leadership positions.

 

Position Descriptions

Page 29

   

Directors receive an in-depth orientation when they become Board members. Regular site visits are organized for operating facilities and offices. While site visits were impacted by the COVID-19 pandemic in 2020, Directors participated in virtual training and education on special topics by videoconference. In addition, special topics of focus or interest are addressed at Board dinners and meetings. Board members are encouraged to continue to pursue education to familiarize themselves with the Company’s business, investments and key Company personnel.

 

Orientation of Directors and Continuing Education

Page 39

   

Creating a culture of integrity begins with the tone at the top. Directors, Officers and employees are required to annually acknowledge that they have reviewed and understand the Emera Code of Conduct, which itself is overseen by the Nominating and Corporate Governance Committee.

 

Ethical Business Conduct

Page 42

   

New Directors are recruited on the basis that they will make a strong contribution and have the background, diversity, skills and experience needed by the Board in view of the Company’s strategy.

 

Nomination of Directors and Director Recruitment Process

Page 29

   

The Company maintains compensation for Directors designed to recognize the substantial time commitment required to oversee management of the Company and to align Directors’ interests with the long-term interests of shareholders.

 

Director Compensation

Page 37

   

Four standing Committees assist the Board in carrying out its responsibilities: the Audit Committee; the Management Resources and Compensation Committee; the Nominating and Corporate Governance Committee; and the Health, Safety and Environment Committee. Special committees are struck from time to time as needed in regard to specific matters.

 

Committees of the Board of Directors

Page 44

   

The Board annually assesses its performance in order to find ways to improve its effectiveness and that of the Chair, individual Directors and the Board Committees.

 

Board and Director Performance Assessments

Page 34

   

In conjunction with the Board and Director assessment work, Directors reflect on strategy work over the year and recommend actions to be undertaken in the following year to carry out strategy. This work informs the Company’s setting of its priorities and goals for the following year, including the CEO’s objectives, and provides a guide for tracking of progress throughout the year.

 

Board and Director Performance Assessments

Page 34

   

Emera Directors are always interested in receiving shareholders’ views about the Company. Shareholders are able to communicate directly with the Chair of the Board or other independent Directors through private and confidential correspondence.

  Communication with Directors and Shareholder Engagement Page 47
 
Please read Emera’s entire Statement of Corporate Governance Practices on the following pages for more important details about the Company’s governance practices.

 

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BOARD OF DIRECTORS

BOARD OF DIRECTORS CHARTER

The Board of Directors believes that clear accountabilities lead to the best governance and therefore maintains a Charter for the Board. Under the Charter, the Board is responsible for overseeing the management of the business of the Company and for providing stewardship and governance for the long-term success of the Company. The Charter describes the duties and responsibilities of the Board in matters of strategic planning, independence and integrity, risk management, leadership and succession, financial reporting, corporate communications, public disclosure, and corporate governance.

The Board of Directors Charter was reviewed earlier this year and amendments were adopted to ensure it appropriately reflects the Board’s responsibility. The most recent changes to the Charter highlight the Company’s ESG values. This new section underlines the Board’s responsibility to oversee management’s approach to addressing Emera’s ESG impacts, risks and opportunities which are most important to its business performance and to key stakeholders. Emera’s ESG commitments are core to our strategy. We are committed to transparency and we recently enhanced our disclosure in our annual Sustainability Report with the addition of both the Sustainability Accounting Standards Board and Task Force on Climate-related Financial Disclosure frameworks. Emera’s Sustainability Reports with our latest ESG highlights are available at www.emera.com/sustainability.

The Board Charter is attached to this Circular as Appendix “A”. We encourage you to carefully review the Charter for more detail about the responsibilities of the Board in these areas.

DIRECTOR INDEPENDENCE

All Emera Directors are independent from management, except for Mr. Balfour, who is President and CEO, and Mr. Ramil. Mr. Ramil, who was President and CEO of TECO at the time it merged with Emera on July 1, 2016, is not considered independent. He retired as President and CEO of TECO in August 2016 and he joined the Emera Board in September 2016. The question of his independence is a matter for determination by the Emera Board under applicable Canadian securities laws.

Use of the term “independent” in relation to a Director in this Circular means a Director is independent as defined under applicable Canadian securities laws and, in particular, is free of any direct or indirect material relationship, which could, in the view of the Board of Directors, be reasonably expected to interfere with the Director’s independent judgment.

In making a determination about the independence of Mr. Ramil, the Board considered the definitions of independence adopted by proxy advisory firms such as ISS and Glass Lewis, which include a five-year period during which a former CEO of an acquired company is not considered independent. But for the Board’s decision to apply the above five-year period set by third-party proxy advisory firms for a former CEO of an acquired company, the Board has determined that Mr. Ramil is in all other respects an independent Director. The Board will review Mr. Ramil’s independence status in September 2021, following the fifth anniversary of his joining the Board.

Except in regard to Mr. Sergel, who receives a retainer for being a member of the Board of Emera’s subsidiary Emera US Holdings Inc., Directors receive no other remuneration from Emera other than Directors’ retainers, fees or retainers for service as Chair of the Board or Chair or member of a Committee. Ms. Sheppard receives an all-inclusive annual retainer as Chair of the Board of Emera. As noted earlier in the Circular, Mr. Balfour does not receive any additional compensation for his services as a member of the Board of Emera or as a member of the Board of any of Emera’s subsidiaries or investments, beyond his compensation as Emera’s President and CEO.

The Company’s Articles of Association provide that no more than two Directors may be employees of the Company or of a subsidiary or affiliate of the Company. Mr. Balfour, as President and CEO of the Company, is the only Director employed by the Company.

INDEPENDENT CHAIR

Ms. Sheppard, the Chair of the Board, is an independent Director. The Articles of Association of the Company require that the Chair of the Board and the President and CEO be separate individuals.

 

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POSITION DESCRIPTIONS

Chair of the Board

The Chair provides leadership to the Board, in order that it may fulfill its duties effectively, efficiently and independent of management. The Chair’s role is to see that the Board and shareholder meetings function effectively. The Chair leads the Board discussions and represents the Board in providing additional advice and counsel to the President and CEO, and senior leadership. Under the leadership of the Nominating and Corporate Governance Committee, the Chair participates in the recruitment and retention of Directors and oversees appropriate processes to determine that the Board of Directors has the requisite skill sets needed by the Company. The Chair also leads the conduct of an annual assessment of the effectiveness of the overall Board and its members. For the full text of the Chair of the Board of Directors Charter, visit www.emera.com/governance.

Committee Chairs

The Board has adopted position descriptions for each Committee Chair, which detail the duties of the Committee Chairs. Each Committee Chair is required to provide leadership to the Committee members and support the Committee’s effective operation to fulfill its mandate. For the full text of the position description for Committee Chairs, visit www.emera.com/governance.

President and Chief Executive Officer

The President and CEO is responsible for leadership of the Company, its people, strategic planning, financial results, overall performance, and succession planning. He is to define, communicate and implement the strategic direction, goals and core values of the Company with a view to ensuring long-term success and value creation for all stakeholders. These roles and responsibilities of the President and CEO are contained in his employment contract. The President and CEO’s employment contract is reviewed by the Chair of the Board of Directors and the MRCC, and it is approved by the Board of Directors.

Among the various responsibilities of the Board, CEO selection is of critical importance. The Board oversees the succession planning program for the Chief Executive Officer. For more information about succession planning, see Succession Planning and Leadership Development in the Statement of Executive Compensation.

BOARD SIZE

The Articles of Association provide that the number of Directors on the Company’s Board must not be less than eight and not more than fifteen. Eleven Director nominees are being proposed for election at the 2021 Annual Meeting.

NOMINATION OF DIRECTORS AND DIRECTOR RECRUITMENT PROCESS

The Nominating and Corporate Governance Committee (“NCGC”) is responsible for providing the Company with a list of nominees for election as Directors at the Company’s Annual Meeting of Shareholders. In developing a list of nominees, the NCGC evaluates the size of the Board and the mix of skills and experience of its Directors and its diversity overall, including the level of representation of women on the Board (required to be at least 30 per cent as noted below under Board Diversity).

Director nominees must, in the opinion of the members of the NCGC, be able to fully discharge their duties as Directors and contribute to the broad range of issues which come before the Board for consideration. They must be able to devote the time necessary to prepare for and attend meetings of the Board and Committees of the Board to which they may be appointed. The NCGC regularly evaluates the expected turnover of Directors in advance of their retirement from the Board and develops an effective succession plan.

Working with the Board Chair, the NCGC considers recruitment in the context of the age and tenure of current members and considering the Board’s overall policy of ensuring renewal and orderly Board succession.

The NCGC will consider the likely potential tenure of a Director candidate before making a selection. This is factored into the selection decision having regard to the current make-up of the Board, the skills and experience the candidate offers relative to those of the other Directors and keeping in mind the age of Directors. Of the proposed slate of Directors, three Director nominees have served on the Board for more than a decade and three Director nominees have served for less than three years. This represents an appropriate mix of longer-serving Directors with a history on the Emera Board, and Directors that are newer to Emera, who bring a fresh perspective and approach to the Company’s Board. For more information about the average age and tenure of Emera’s Director nominees, refer to the section entitled Mechanism for Board Renewal.

 

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DIRECTORS’ MEMBERSHIP ON OTHER PUBLIC COMPANY BOARDS

Public company board membership for each Director during the last five years is set forth in their biographies in the section entitled Director Nominees.

COMMON MEMBERSHIPS ON BOARDS OF PUBLIC COMPANIES

Currently no other public company includes on its board two or more of Emera’s Directors.

MECHANISM FOR BOARD RENEWAL

Emera has no term limits for its Directors. The Board of Directors oversees processes for renewal of the Board, which balance many factors, and have as their ultimate objective the fulfillment of the fundamental responsibility of the Board to provide stewardship and good governance for the Company. Those processes primarily include: a robust Director recruitment process, internal governance practices that regularly assess each of the Board’s desired skills, and the conduct of an annual performance assessment of the Board, its Committees and individual Board members, all of which provide for renewal in a deliberate manner.

Emera’s governance practices prescribe that planned departures of Board members in any one year will not exceed two Directors. This practice contributes to Board renewal in a deliberate manner while ensuring continuity.

A rigorous annual performance assessment takes place under the leadership of the Board Chair with support from the NCGC and is described in greater detail under Board and Director Performance Assessments. The annual performance assessment provides information that is relevant for Board renewal.

In November 2016, the Board of Directors adopted a governance practice intended to provide for Board renewal, considering the removal in 2016 of the age limit from Emera’s Articles of Association. Under this governance practice, when recommending the nomination of Directors for election, the NCGC members must consider certain principles in relation to appropriate and balanced renewal of the Board. Those principles are as follows:

Board Renewal Principles

The NCGC adheres to a philosophy of promoting deliberate and balanced Board renewal. In keeping with such philosophy, it considers the following principles in respect of the list of Director nominees:

 

  (a)

Age: as Directors approach 70 years of age, the NCGC assesses the needs of the Board, based on the Board’s complement and other relevant factors. Where a determination is made that such Director will be retiring, the NCGC begins the replacement process.

 

  (b)

Tenure: the length of time that a nominee has served on the Company’s Board of Directors is considered, subject to the Guideline on Board Tenure, with a view to the Board having Directors with an appropriate mixture of tenures.

 

  (c)

Average age: the average age of all of the Company’s Director nominees is determined and considered.

 

  (d)

Average tenure: the average tenure of all of the Company’s Director nominees is determined and considered.

 

  (e)

Other relevant factors: the NCGC considers any other factor Committee members determine to be relevant in the promotion of orderly succession and balanced renewal of membership on the Board, having as its ultimate objective the constitution of a Board of Directors which fulfills the fundamental responsibility of providing stewardship and good governance for the Company.

In practice, as a Director approaches age 70, the Board assesses the needs of the Board and may immediately commence a search. Depending on factors listed and taking a view as to the appropriate transition period, the transitioning Director may or may not be proposed for nomination but should not expect to be nominated after the age of 72. This flexibility allows for an orderly Board transition and balances the desire for renewal against the need for continuity and stability.

Application of Board Renewal Principles

The NCGC applied the principles to the Director nominees for Emera’s 2021 Annual Meeting. The Committee considered the average age of all of the Company’s Director nominees for election at the 2021 Annual Meeting, which will be 64.35 (in 2020 it was 63.52 years, and in 2019 it was 63.17 years), and the average tenure of all of the Company’s Director nominees as of the 2021 Annual Meeting, which will be 6.68 years (in 2020 it was 6.34 years, and in 2019 it was 5.69 years). In applying the Board Renewal Principles as described, the NCGC has recommended to the Board of Directors all the Director nominees presented earlier in this Circular.

 

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Board Tenure Guideline

In February 2021, on the recommendation of the NCGC, the Board adopted the following Board Tenure Guideline:

In support of the Board Renewal Principles, the Board has set a guideline that Directors may serve on the Board for a maximum tenure of 15 years. Re-nominations for election as Directors will be based on the recommendation of the Nominating and Corporate Governance Committee taking into consideration the needs of the Board, the best interests of Emera given its strategic objectives and the results of the annual Board and Director Performance Assessment.

As of the date of Emera’s 2021 AGM, all Director nominees shall have served on the Board for less than 15 years.

DIRECTOR’S OCCUPATION

The Directors have also instituted a policy which requires them to submit their resignation as a Director if there is a significant change in their principal occupation. The resignation is then considered by the Board which determines if the circumstances warrant acceptance of the resignation, whether due to a conflict of interest arising by virtue of a new principal occupation or otherwise.

COVID-19 PANDEMIC

Emera activated pandemic planning protocols to respond to the global COVID-19 pandemic early last year. In March 2020, the Company elevated its response plan to address increasing risks from COVID-19 to our employees, customers and communities. With health and safety as our top priority, the Company implemented restrictions on all business travel and new procedures and protocols for our operations. Directors have observed these travel restrictions and public health directives concerning travel resulting in no face-to-face meetings being held since the start of the pandemic. However, the business of the Board and its Committees has continued, uninterrupted, through videoconference technology. The governance response to the COVID-19 pandemic was considered effective. It involved periodic updates with comprehensive information on the response to the COVID-19 pandemic across all of Emera’s operating companies. It also included the scheduling of more frequent Board meetings during the initial months of the pandemic to provide appropriate oversight of the Company’s pandemic response.

DIRECTORS MEET WITHOUT MANAGEMENT

There were 27 Emera Board and Committee meetings during 2020. The Board and each Committee have adopted the practice of meeting in an in-camera session, during which the President and CEO and all other members of management are excluded. This practice has been implemented and the Board held an in-camera session at each Board and Committee meeting.

As the former President and Chief Executive Officer of TECO, who joined Emera’s Board following the closing of the TECO acquisition in 2016, John Ramil provides excellent industry and jurisdictional expertise. Recognizing the importance of independent dialogue, the Board developed a separate protocol concerning Mr. Ramil’s participation on the Board during his early tenure as a Director. That protocol meant that Mr. Ramil recused himself for a portion of each meeting. In 2018, it was determined this protocol was no longer necessary, and that Mr. Ramil should participate in all in-camera sessions.

The Board generally holds an evening session before the day of a regularly scheduled Board meeting and prior to the Board’s annual strategy meeting. As a governance practice, and at least once a year, the non-executive Directors conduct such an evening session that excludes the President and CEO and all other management. See Board Dinner Sessions for more information.

BOARD DINNER SESSIONS

Since the declaration of the global COVID-19 pandemic in March 2020, the Emera Board has avoided all in person meetings, including its regularly scheduled pre-meeting Board dinners. However, in lieu of Board dinners, Directors have scheduled and held educational sessions by videoconference on a variety of relevant topics. These sessions are treated as an opportunity to accomplish many important governance objectives, including:

 

   

Meeting as Directors in an atmosphere that is not a Board meeting;

 

   

Meeting in a less formal atmosphere with the CEO and other senior officers;

 

   

Holding educational sessions on important topics for the Company’s business and strategic direction;

 

   

Meeting high-potential employees to advance the succession planning for the Company; and

 

   

Strengthening Directors’ working relationships.

 

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CORPORATE STRATEGY

Oversight and guidance of the corporate strategy is one of the primary roles of the Board. Led by the President and CEO, the Management team works with the Board to set the strategy agenda for the year, including annual individual interviews with each Director in addition to discussions with the Board as a whole.

A specific and significant component of every scheduled Board meeting includes an update and discussion on strategy and related matters, including trends in the industry, growth initiatives, financial forecast updates and new risks and opportunities. These updates serve to keep the Board aware of changes in the market, industry and within Emera, as well as giving the Board an opportunity to provide insight and direction throughout the year on strategy.

Each year, at least one and often two board meetings are dedicated to strategy. In 2020, strategy-focused meetings were held in June and September. These meetings included the annual strategic update on industry trends including the company’s strategic positioning related to the customer-driven trends of decarbonization, decentralization and digitalization, an updated long-term financial forecast, a review and analysis of industry peers, an overview of strategic signposts that management is regularly monitoring in its ongoing assessment and review of strategy, updates on specific components of strategy including talent and digital strategies and other key strategic initiatives and projects. 2020 also included a presentation and discussion on Emera’s focus areas for growth. The June meeting also included significant scenario analysis of the current and long-term impacts of COVID-19 on the Company as well as key industry trends.

Our strategy is designed to both prepare for and capitalize on the customer-driven trends of decarbonization, decentralization and digitalization facing our industry. Broadly, Emera’s strategy continues to focus on safely delivering the cleaner, reliable and affordable energy our customers count on. We continue to drive organic growth through regulated investments in cleaner energy, reliability, infrastructure renewal and system expansion.

Environmental, Social and Governance

The Board reinforced Emera’s ESG commitments as core to our strategy and our culture. Last year, we took steps to better articulate our commitments and our approach to managing the risks and opportunities related to ESG. We also increased our ESG disclosures and governance with the addition of two disclosure frameworks to our reporting, namely: the Sustainability Accounting Standards Board and the Task Force on Climate-related Financial Disclosures disclosure frameworks. We also enhanced executive oversight of ESG and established a Sustainability Management Committee mandated to oversee the risk management, disclosures and focus areas for the Company.

Decarbonization and 2050 Net-Zero Vision

Our focus on building a more sustainable energy future shapes our environmental commitments. Decarbonization has been central to our strategy for more than 15 years and has been a key driver of our growth and innovation. Throughout 2020, the Board and Management examined and discussed Emera’s decarbonization progress, plans and pathways, which were finalized and shared publicly in February 2021 as Emera’s Climate Commitment.

Building on its strong decarbonization track record, Emera is continuing its efforts by establishing clear carbon reduction goals and a vision to achieve net-zero carbon emissions by 2050.

In 2020, we achieved a 39 per cent reduction in CO2 over 2005 levels. With existing technologies and resources and the benefit of supportive regulatory decisions, we plan and expect to achieve the following goals compared to corresponding 2005 levels:

 

   

A 55 per cent reduction in carbon emissions by 2025;

   

An 80 per cent reduction in coal usage by 2023 and the retirement of our last existing coal unit no later than 2040; and

   

At least an 80 per cent reduction in carbon emissions by 2040.

Emera seeks to achieve these goals and realize our net-zero vision while staying focused on enhancing reliability, maintaining affordability, adopting emerging technologies and working constructively with policymakers, regulators, partners, investors, and our communities.

 

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Inclusion and Diversity

Emera is committed to the promotion of inclusion and diversity throughout the Company. Our commitment to our people, customers and communities reflects Emera’s social values and culture. We strive for a workplace that:

 

   

Reflects its communities and diverse customer base, enabling us to better understand the needs of our customers and the communities we serve;

 

   

Helps position Emera as an employer of choice to recruit, retain and engage high-performing talent; and

 

   

Fosters better decision-making with the benefit of more diverse perspectives and experiences.

Emera is now in its third year of a multi-year Inclusion and Diversity Strategy to align best practices across its operations. To support this, we have undertaken several initiatives:

 

   

Conducting unconscious bias training for all Emera leaders;

 

   

Supporting strong Inclusion & Diversity employee networks;

 

   

Gathering self-identification data to ensure our teams reflect our communities;

 

   

Undertaking the process to recruit a Director of Diversity and Inclusion; and

 

   

Establishing a $5 million fund to support community efforts to advance diversity and inclusion.

The Board of Directors has requested and received inclusion and diversity training and will be receiving further education and training in this area.

Gender Diversity and Women in Executive Officer Appointments

While Emera does not have targets for women in executive officer positions, management monitors and encourages the development and progression of women into leadership positions within Emera and its subsidiary companies. Management believes that diversity among the senior executive team within the Emera group of companies serves the best interests of the Company.

At Emera Inc., 38 per cent of executive officers are female. Across all Emera companies, an average of 34 per cent of executive officers are female. Among the executive officers(1) of Emera Inc. and its major subsidiary,( 2) Tampa Electric Company, 18 are female, representing 39 per cent (in 2020 there were 16 female executive officers, representing 37 per cent). Currently, four of our companies are led by women (Tampa Electric, Emera Energy, Grand Bahama Power Company, and Dominica Electricity Services).

Management continues to be focused on ensuring Emera’s hiring and pay practices promote equity between men and women. Progress is being made and we continue to be committed to:

 

1.

Analyzing pay equity annually to:

 

  a.

Monitor annually the rates of women in leadership and senior leadership roles;

 

  b.

Undertake regular wage gap analysis to track progress and identify challenges by affiliate;

 

  c.

Exercise selective pay increases if wage disparity exists; and

 

  d.

Examine our recruitment strategies to ensure equity in pay at entry into the organization.

 

2.

Developing and promoting programs, such as the Engineer in Training program at Nova Scotia Power, that are focused on increasing female participation in our industry, particularly for traditionally male-dominated roles. Approximately 57 per cent of the Engineers in Training hired since 2017 have been female.

 

(1)

The term executive officer is defined as the Company’s Board Chair, president, a vice president in charge of a principal business unit, division or function, or any person who performed a policy-making function in respect of the issuer.

(2)

Major subsidiary means a subsidiary of the Company, the assets or revenue of which are 30 per cent or more of the consolidated assets or revenue of the Company as included in the financial statements of the Company for a relevant period. Only Tampa Electric Company meets this definition.

 

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Our Commitment to Safety

Safety is Emera’s number one priority and the Company is committed to fostering a strong “speak up” culture that supports safety performance. In 2020, Emera’s teams adapted quickly to implement new safety procedures and protocols to respond to the global COVID-19 pandemic to keep employees, customers and communities safe. Last year, the Company implemented an Emera-wide safety management system and Emera saw the lowest OSHA injury rate and lost-time injury rate in the Company’s history. However, two recent contractor fatalities are a reminder that the Company needs to stay relentlessly focused on safety. In 2021, initiatives will focus on prevention of serious injuries and fatalities, and the management of high-risk activities. Another area of focus is safety leadership training, including behavioural aspects of safety management and improving hazard identification. Emera’s team is more resolved than ever to achieve an injury-free workplace.

Investing in Our Communities

Throughout its Community Investment Program, Emera is committed to helping to build stronger, safer and more innovative communities where we live and work. In 2020, we invested $16 million in our communities, including over $6 million to organizations providing critical aid to those most affected by the COVID-19 pandemic. Our contributions helped to provide assistance with energy costs, food, shelter and mental health support.

Information Security Oversight and Cybersecurity

The Company increasingly relies on information technology systems and network infrastructure to manage its business and safely operate its assets, including controls for interconnected systems of generation, distribution and transmission as well as financial, billing and other business systems.

The Company’s reliance on technology exposes it to potential risks of business interruption or the unavailability, release, destruction or misuse of critical, sensitive or confidential information due to cyberattacks.

The Company seeks to manage these risks by aligning to a common set of cybersecurity standards, periodic security testing, program maturity objectives and strategy derived, in part, from the National Institute of Standards and Technology’s Cyber Security Framework, including incident management, vendor management, configuration management and employee communication and training. With respect to certain of its assets, the Company is required to comply with rules and standards relating to cybersecurity and information technology including, but not limited to, those mandated by bodies such as the North American Electric Reliability Corporation and Northeast Power Coordinating Council.

The status of key elements of the Company’s cybersecurity program is reported to the Audit Committee on a quarterly basis and the Board receives reports on that work through the Audit Committee. In addition, the Board oversees the risk and mitigation plans in relation to these risks, as updated and reported on quarterly in a risk dashboard provided to Directors at each regularly scheduled Board meeting.

BOARD AND DIRECTOR PERFORMANCE ASSESSMENTS

The Board annually assesses its effectiveness to find ways to improve its performance.

Each year, the NCGC, in consultation with the Board Chair, and with the intention of continuously improving, determines the process by which assessments of the Board, Directors, Committees and individual Committee members will be conducted. The process has included the use of questionnaires and one-on-one interviews with each Director by the Board Chair. A written report from the Board Chair on the assessment is provided to the NCGC and the Board of Directors. The Board considers the report, its findings and a set of priority actions for the year at a Directors-only session which is attended by the President and CEO for only a portion of the session. Progress is monitored throughout the year with oversight on that process by the NCGC. In 2020, the NCGC determined that from time to time the assessment process may be supplemented with the engagement of a third-party consultant to assist with the process of conducting the assessment. A consultant was engaged to assist with the 2020 Board and Director performance assessment (please see 2020 Assessment below for more detail).

 

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2019 ASSESSMENT

Overall, the 2019 Assessment found that the Board and Director performance and effectiveness were very strong. Board members take pride in the Company’s strong governance. The Assessment resulted in several priority actions for 2020 in the areas of the Company’s strategy and business, its organizational structure and capacity and with respect to Board and Committee effectiveness. With the assistance of the NCGC, the Board Chair reviewed and reported to the Board on progress made to address those priorities.

2020 ASSESSMENT

The Chair of the Board interviewed each non-executive Director as part of the 2020 Board and Director Performance Assessment. A series of questions was sent to each Director for advance consideration. The questions pertained to several themes, including:

 

   

Board and Committee effectiveness;

 

   

Corporate governance;

 

   

Board composition and succession;

 

   

An assessment of their own performance as Directors;

 

   

An assessment of their peer Directors on the Board;

 

   

Emera’s strategy and business;

 

   

Organizational structure and capacity; and

 

   

The CEO’s 2020 evaluation, and his 2021 CEO goals and objectives.

The assessment of the Chair of the Board was conducted in a meeting of all Directors that excluded the Board Chair and the President and CEO and was led by the Chair of the NCGC. Directors were also given an opportunity to provide their assessment of the Chair of the Board in a one-on-one format with the Chair of the NCGC in advance of the meeting.

Third-party Consultant

The NCGC determined that while the traditional annual assessment process conducted by the Chair was robust and effective, a third-party consultant should be engaged as part of the 2020 Board Performance process in order to provide additional insights. Separate interviews with each Director were scheduled by the consultant, who also interviewed the President and CEO and some of his direct reports as part of the process. A report of the consultant on the findings from the assessment process was provided to the Board Chair and the Board of Directors. The consultant also provided the Chair of the NCGC with a briefing on the findings that related to the Board Chair in support of her assessment.

2020 ASSESSMENT FINDINGS

The principal themes that emerged from the 2020 Board and Director Performance Assessment related to strategy and business, organizational structure and capacity as well as Board and Committee effectiveness.

Directors were satisfied with the quality and the integrity of the Board and its membership. Members are very supportive of the Board’s meeting practices.

On recruiting of Directors, the Board will focus on diversity of its membership and the ultimate size of the Board. Improvements in the way the Board and the Committees operate will also be considered, though the function of each are considered strong.

The NCGC has devoted considerable time to successfully advancing the Board’s renewal, while objectively determining the required skills of the Board and advancing diversity. Diversity of Directors at the Company’s subsidiary boards also remains a focus.

2021 OBJECTIVES

In the course of performing the Board and Director performance assessments, Directors assessed 2020 progress and proposed areas of future focus as it relates to strategy and management performance. These included:

Strategy and Business: The Company’s long-term growth priority continues to be making prudent organic investments within the existing portfolio of regulated utilities, most of which entails investments in decarbonization, reliability, infrastructure renewal and infrastructure expansion capital projects. Outside of the Company’s utilities, Management continues to pursue initiatives focused on exploring and testing Emera’s role in the energy sector of the future and the associated risks and opportunities,

 

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largely stemming from the newer customer-driven industry trends of decentralization and digitalization. The strategy process has been enhanced, with the Board’s year-round oversight of strategy resulting in significant progress and increased alignment. Ongoing work will focus on the Company’s growth strategy, and, in an effort to continue to deliver competitively attractive risk adjusted growth in earnings and cash flow over the long term, is principally focused on organic rate base growth. Opportunities for growth through acquisition also remains an area of engagement for the Board as it continues to engage with Management in its refinement of the strategic framework and criteria for possible acquisitive growth. ESG impacts, risks and opportunities are important and growing areas of focus in strategic discussions. Significant work in the area of enterprise risk and, in particular, high-impact risks was advanced in 2020 and remains an area of focus for 2021.

Organizational Structure and Capacity: Senior management succession plans have been a focus of the Board and have been advanced with organizational changes identified to facilitate development of potential internal candidates. Board processes have included a program to expose prospective leaders to the Board. Emera’s affiliate governance model has been an area of ongoing focus and refinement by management, with input and oversight from the NCGC, and is overall considered to be structured effectively. Strategy engagement within management has been enhanced with the establishment of a Strategy Council that includes cross affiliate and cross functional executive engagement. Significant progress was made in 2020 in several areas, including senior management succession and the Company’s important ongoing inclusion and diversity initiatives. Areas of ongoing focus include leadership development; greater Board exposure to a broader succession pool; workforce diversity; workplace culture; maintaining Emera’s values; cross-functional approach to ESG; risks and opportunities from disruptive technologies; and harnessing value through digitalization. The long-term effects of the COVID-19 pandemic on the workplace will also be considered.

BOARD DIVERSITY

Diversity at the Board level is an important strategic objective of the Board and is incorporated into the Board’s succession planning and recruitment processes. Consistent with the Company’s goal of achieving and maintaining a Board of Directors with a diverse mix of experience, skills and backgrounds, when assessing Board composition or identifying suitable candidates for appointment or re-election to the Board, the NCGC considers candidates using objective criteria having due regard to the benefits of diversity and the needs of the Board. In addition to considering business experience, geography and age, the NCGC considers diversity of gender, race, Indigenous status and other distinct characteristics.

To ensure that there are a significant number of women on the Company’s Board of Directors, the NCGC adopted in 1994 a formal corporate governance practice, which has been incorporated into the NCGC charter and which requires that a minimum of 30 per cent of the members of the Board of Directors are women. The list of Director nominees for the 2021 Annual Meeting includes four women out of 11 Director nominees, or 36 per cent, which exceeds this minimum requirement (the 2020 Annual Meeting also included four women out of 11 Director nominees, or 36 per cent).

Emera’s commitment to diversity extends beyond gender. While the Board currently has no members who identify as aboriginal, a member of a visible minority or as a person with a disability, the Company is focused on establishing and maintaining a Board with a diverse mix of experience, skills and backgrounds. The NCGC considers candidates having due regard to the benefits of diversity. Its current succession focus for Board recruitment is on candidates that offer US electric utilities experience and racial and ethnic diversity to the Board. The NCGC has retained qualified external recruiters to help identify candidates of diverse backgrounds and characteristics. These recruiters are mandated to seek diverse candidates who meet the skills, experience and diversity objectives established by the NCGC.

Subsidiary Board Diversity

Emera has made significant progress in this area. Of the 20 external directors that serve on the Boards of our four largest subsidiaries (Nova Scotia Power, Tampa Electric, Peoples Gas and New Mexico Gas), 45 per cent are female and 30 per cent are Black, Hispanic or Indigenous. Diversity on our subsidiary boards remains an ongoing focus.

 

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COMPENSATION

EXECUTIVE COMPENSATION

On the recommendation of the Management Resources and Compensation Committee (“MRCC”), the Board of Directors determines the compensation for the Company’s senior executives and other officers of the Company. See Compensation Discussion and Analysis with respect to compensation of the Company’s named executive officers.

DIRECTOR COMPENSATION

The Board of Directors determines the compensation for the Company’s Directors on the recommendation of the NCGC. The compensation of Directors is designed to recognize the substantial time commitments required to oversee management of the Company. It is intended to attract and retain highly skilled and experienced individuals to serve on Emera’s Board, and to ensure alignment with shareholders’ long-term interests. Appropriate compensation for Directors, independently determined, is also intended to support their independence of management.

In 2020, the Company removed meeting fees for Directors and moved to a flat fee structure. It also removed per meeting travel fees and moved to a single $10,000 travel allowance. The annual retainer for Directors in 2020 was $227,500 per annum, payable as follows:

 

   

$85,000 cash; and

   

$142,500 in DSUs.

To address the impact of changes in the Canadian and US foreign exchange rate, the annual cash retainer and committee retainers for US-domiciled Board members are paid in US dollars using a one-to-one conversion rate to the Canadian dollar.

Directors were not travelling to the Company’s Board and Committee meetings since the start of the COVID-19 pandemic in March 2020 and met by videoconference instead. In light of this, the Board decided that the Director travel allowance should not be paid for the second, third and fourth quarters of 2020. It is expected Directors would continue to forgo their entitlement to the travel allowance until the quarter in which they begin travelling again to Board and Committee meetings.

For more details on total compensation received by Emera Directors in 2020, see Compensation of Directors in 2020 earlier in the Circular.

ANNUAL REVIEW

The NCGC annually reviews the compensation of Directors to ensure it is appropriate.

The Committee reviews the compensation practices of publicly traded companies similar in size and complexity to Emera to determine whether the Directors are appropriately compensated for the responsibilities and risks involved in being a member of the Company’s Board. The review is based upon publicly available information concerning Directors’ compensation and the advice of Mercer (Canada) Limited, a third-party compensation consultant.

The NCGC has adopted the 50th percentile as a target for Director compensation and has determined it would be appropriate for Emera to continue to position total compensation of Directors at approximately the median of its peer group, which is the average of the Canadian and US sub-groups. The peer group used for Director compensation purposes is the same as the benchmarking comparator group used for senior executive compensation purposes and disclosed in the Statement of Executive Compensation later in the Circular.

 

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Based on the approach to Director compensation described above and the recommendation of the NCGC, the Board approved the following changes to the retainer and equity compensation for Emera Directors and the annual retainer for the Chair of the Board, effective January 1, 2021.

 

   

The cash component of the Board Chair’s annual retainer was increased by $12,500 for a total of $225,000 and the equity component of the Board Chair’s annual retainer was increased by $12,500 for a total of $225,000. As a result of this increase, the Board Chair’s total annual compensation is $450,000.

   

The cash component of each Director’s annual retainer was increased by $7,500 for a total of $92,500 and the equity component of each Director’s annual retainer was increased by $17,500 for a total of $160,000. As a result of this increase, the total annual compensation for each Director is $252,500.

DIRECTOR SHARE OWNERSHIP GUIDELINES

Director common share and/or DSU ownership is viewed by Emera as an important means of enhancing the alignment of Director and shareholder interests. Under guidelines established by the Board of Directors, within a prescribed time frame, each Director must own Emera common shares and/or DSUs with a market value of three times the annual Board retainer. Based on the annual retainer for Emera Directors in effect on January 1, 2021 as described above, under these guidelines each Director must own Emera shares or DSUs, or a combination of the two, worth $757,500 within five years following their appointment date or within five years of any change to the Director’s compensation, whichever is the later date. Notwithstanding the increase in Director compensation on January 1, 2021, the Board did not reset the date by which current Directors must meet the share ownership guideline threshold where they have not already done so.

Details of each Director’s share and DSU ownership, and status under the Share Ownership guidelines, is shown in each Director nominee biography earlier in this Circular. All of Emera’s Director nominees are in compliance with these guidelines.

DIRECTORS ARE INCREASING THEIR SHARE/DSU OWNERSHIP OVER TIME

By virtue of the compensation payable in DSUs, more than 63 per cent of the annual retainer for Emera Directors will be paid in DSUs, which mirror the value of Emera common shares. The Directors increase their DSU ownership by at least $160,000 per annum. A majority of the Director nominees have elected to receive DSUs in lieu of cash compensation they would otherwise be entitled to as Emera Directors.

MAJORITY VOTING FOR ELECTION OF DIRECTORS

The confidence of shareholders in the actions of the Board and management is important. In order to provide a mechanism for shareholders to express that confidence in each Director, the Board has adopted a Majority Voting Policy for Directors. The Policy states:

Should a Director nominee, in an uncontested election at a meeting of shareholders of Emera Inc. at which Directors are to be elected, receive a majority of “withheld” votes from his or her election as a Director (a “Majority Withheld Vote”), the individual shall submit his or her resignation to the Board for consideration immediately following such shareholders’ meeting.

The votes determining a Majority Withheld Vote shall be the total votes cast by ballot by shareholders and proxyholders, or if a ballot vote was not conducted, shall be the total votes represented by proxies validly deposited prior to the shareholders’ meeting.

The Directors who received a majority “For” vote at the shareholders’ meeting shall consider whether or not to accept the resignation.

If there are less than three such Directors, the entire Board shall meet to consider the appropriate actions to be taken. The resignation of a Director who received a Majority Withheld Vote shall be accepted absent exceptional circumstances and is effective when accepted by the Directors. The determination shall be made within 90 days following the date of the shareholders’ meeting and a news release disclosing such determination shall be issued promptly following such determination. If the resignation is rejected, the news release shall include the reasons for rejecting the resignation. A copy of the press release shall be provided to the Toronto Stock Exchange.

Since the adoption of the Majority Voting Policy in 2008, all Director nominees have received a majority “For” vote at the Company’s meetings of shareholders.

 

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ORIENTATION OF DIRECTORS AND CONTINUING EDUCATION

In order to best bring their skills and experience to the operation of the Board, new Directors receive an in-depth orientation to the Company’s executive leaders, business, strategy, principal risks, financial information and governance practices. This allows them to effectively and efficiently step into their new role as Director and discharge the responsibilities of that role. The Board and management have built and continue to expand a long-term program of training and information sharing for Directors to enhance their effectiveness and reinforce a collegial working relationship among members of the Board.

Orientation sessions are attended by the President and CEO and other executive officers or leaders of key subsidiaries. The Chair also attends the orientation with a new Director. A reference manual is provided in advance of the session that includes:

 

  (a)

Recent annual and interim MD&A and financials, Management Information Circular and Annual Information Form;

 

  (b)

Board and Committee Charters;

 

  (c)

Strategic Plan and Business Plan and Budget;

 

  (d)

Guide to the Company’s management structure;

 

  (e)

Insider trading guidelines;

 

  (f)

Emera’s Code of Conduct; and

 

  (g)

Minutes of previous Board meetings.

CONTINUING EDUCATION FOR DIRECTORS

The Board, with the support and oversight of the NCGC, regularly seeks opportunities to update, educate and inform the Directors in areas they request or that management determines are relevant to issues facing the Company.

The Board and Committees receive regular presentations from Management updating Directors about market and industry conditions and trends that may impact the Company’s business and influence its strategy. From time to time, the Board receives specialized presentations on various matters of significance to the Company.

Annually, the Board has also been provided with opportunities to visit operational facilities to help Directors to get to know leaders, understand management structure and more fully understand the business. Given the global COVID-19 pandemic, the Emera Board has avoided travel and, therefore, there were no visits to operational facilities in 2020. Site visits are tentatively being scheduled for later in 2021 pending health guidelines regarding travel and gatherings.

Emera adopted a Guideline for Directors’ Attendance at Education Sessions, which is designed to encourage Directors to participate in education sessions from time to time that are directly related to the business of the Company and the performance of their duties as a Director of the Company. The Guideline provides that independent Directors who wish to attend an education session request the approval of the Board Chair to attend a particular education session and receive reimbursement of expenses in accordance with the Guideline. In 2020, Emera Directors participated in relevant education that included sessions presented by the Institute of Corporate Directors in Canada and the National Association of Corporate Directors in the United States.

 

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Directors participated in education sessions and received education materials about specific topics in 2020, as follows below:

 

     
Topic    Date    Participants
     
Business and operations          
     
Government Relations    February    Board members
     

Regulatory & Government Relations Update

Negative Interest Rates Discussion Paper

   May    Board members
     

Capital Markets Overview

Industry Trends

   June    Board members
     

Utility Sector Regulatory Update

State of hydrogen development and its potential role in decarbonization

   August    Board members
     
Subsidiary Governance Update on Charter and Best Practices    September    Nominating and Corporate Governance Committee members and Board Chair
     
US presidential election results – macro and geopolitical and energy sector implications    November    Board members
     

High Impact Risks – Electric Utilities

High Impact Risks – Gas Operations

   September and
November
   Board members
     
Market trends and regulatory updates          
     
Safety – Supplemental Reading Materials    January    Health, Safety and Environment Committee members and Board Chair
     
Future of Natural Gas Industry    March    Board members
     
Presentation on Inclusion and Diversity    September    Board members
     
Executive Compensation and Governance Trends    September    Management Resources and Compensation Committee members and Board Chair
     
Developments in Corporate Governance    September    Nominating and Corporate Governance Committee members and Board Chair
     

Deep Decarbonization

Strategic Role of Natural Gas

   November    Board members

The Board of Directors encourages, and the Company pays the out of pocket costs for, Directors to pursue education sessions provided by third parties that are related to the business of the Company and the performance of their duties as a Director of the Company.

 

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RISK MANAGEMENT

The Emera Board has a comprehensive and multi-faceted approach to risk oversight.

The Board of Directors is responsible for overseeing risk. It is also responsible for overseeing the implementation by management of appropriate systems to identify, report and manage the principal risks of Emera’s business. It is responsible for overseeing the development of Emera’s risk management framework and allocation of responsibilities for risk management, which it does with support from the NCGC. The Board has endorsed a risk statement which articulates the Company’s risk appetite. The risk statement sets out the risk appetite across a number of areas and is intended to provide general guidance for decisions of the Company. The Board considers Emera’s risk profile and oversees Emera’s risk management by reviewing:

 

  (a)

the annual identification and assessment of the principal risks of Emera;

 

  (b)

the process for ongoing monitoring, updating and reporting of the principal risks of Emera;

 

  (c)

the effectiveness of Emera’s mitigation response to its principal risks; and

 

  (d)

the alignment of risk management with Emera’s risk profile, its strategy and its organizational objectives, including capital and resources allocation.

Further, a comprehensive and ongoing risk assessment is part of every major project the Company undertakes. The Board is also responsible for reviewing Emera’s annual insurance program and its uninsured exposure.

Over the course of 2020, the Board oversaw a significant advancement in the way enterprise risk is assessed and reported on to provide greater insight into the current and future state of Emera’s risk posture. This involved two interrelated initiatives which have enhanced governance of enterprise risk at Emera. Under the Board’s oversight, management undertook a robust, in-depth analysis of several of its top high impact enterprise risks where teams identified and assessed the likelihood, impact and maturity of control systems for a number of the Company’s major risks and identified further opportunities for risk mitigation. This work is ongoing in 2021 with respect to other high impact risks. In addition, the previous quarterly risk dashboard was significantly updated and supplemented with a new heat map which identifies for each risk, the inherent risk, the currently mitigated risk, the maturity of the control environment and the directional opportunities for further risk reductions.

The Board also annually evaluates the operation and effectiveness of the Board of Directors, its Committees and the Chair of the Board. That evaluation includes consideration of whether the Board has examined the key risks to the Company’s strategy and business plan. It also invites suggestions for improving the risk management process. More information about this process is included under Board and Director Performance Assessments in the Circular.

The Board has delegated certain risk oversight to the Committees as set forth in their Charters. Notwithstanding such delegation, the Board retains its oversight function and ultimate responsibility for these delegated functions.

Nominating and Corporate Governance Committee (“NCGC”)

The NCGC has responsibility for overseeing the development of a risk management framework and assisting the Board in determining the proper and effective allocation of risk oversight responsibilities.

Management Resources and Compensation Committee (“MRCC”)

The MRCC is responsible for evaluating the compensation programs to determine that they do not reward executive officers for taking inappropriate risks that may harm the interests of the Company and its shareholders. The MRCC conducts a compensation risk review annually to ensure that the compensation policies are designed to take account of and mitigate (a) the incentive opportunities that inadvertently encourage excessive and unnecessary risk-taking, (b) pay structures that inadvertently encourage behaviour that destroys or diminishes long-term value, (c) a lack of appropriate alignment between pay and performance, and (d) payouts which are not aligned with Emera’s business strategy.

Audit Committee

The Audit Committee of the Board of Directors assists the Board in discharging its oversight responsibilities concerning the integrity of Emera’s financial statements, its internal control systems, the internal audit and assurance process, the external audit process and its compliance with legal and regulatory requirements. The Audit Committee has oversight responsibilities for trading and credit risk. It receives the annual update on trading and credit risk activities, and reports to the Board. Cybersecurity risk is also reviewed by the Audit Committee on a quarterly basis.

 

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Health, Safety and Environment Committee (“HSEC”)

The HSEC reviews actions taken by the Company to identify and manage risks related to health, safety and environmental matters which may have the potential to adversely impact the Company’s operations, employees, strategy or reputation. In 2020, the HSEC reviewed detailed updates on the Company’s COVID-19 pandemic response and planning, including the framework for responsible re-entry of employees back into the workplace.

ETHICAL BUSINESS CONDUCT

The Board is committed to sustaining a culture of integrity and ethical business practices throughout the Company.

CODE OF CONDUCT

Emera adopted a new Code of Conduct in 2016 when Emera and TECO closed their merger transaction, replacing Emera’s Standards for Business Conduct and TECO’s Code of Ethics & Business Conduct. When they join, and annually thereafter, Directors, officers and employees of Emera and its subsidiaries are required to sign a form acknowledging they have reviewed, understand, are currently in compliance and agree to comply with our Code.

The Code of Conduct is available on Emera’s website at www.emera.com/governance, or a copy may be obtained by contacting the Chief Human Resources Officer, Emera Inc., P.O. Box 910, Halifax, Nova Scotia B3J 2W5.

The Board regularly reviews the Code of Conduct and makes revisions to update the content in keeping with best practices. Employees are encouraged under the Code to, in good faith, seek advice, raise concerns, and report suspected misconduct related to Emera’s business. Emera does not tolerate retaliation, threats of retaliation, termination from an Emera Company, or other types of discrimination that are directly or indirectly related to the good faith disclosure of suspected unethical activities or violations of laws, regulations or policies.

The Board monitors compliance with the Code of Conduct. There have been no instances of any waiver of compliance with the Code of Conduct for any Director or Officer.

RESPECTFUL WORKPLACE

Emera has a long-standing Respectful Workplace Policy, which clearly condemns harassment, sexual harassment, bullying and discrimination in the workplace. Emera’s Code of Conduct also highlights the Company’s commitment to respect in the workplace and makes it clear there is no place for disrespect in the form of harassment, sexual harassment, bullying or discrimination in the workplace.

In 2018, the Respectful Workplace Policy was revised to be adopted by all operating subsidiaries. The revised Policy highlights the standard process for reporting and addresses harassment, sexual harassment, discrimination and bullying. These revisions have been reflected in the Code of Conduct and in the mandatory training which were each instituted in 2019. The training includes a more robust module on harassment, sexual harassment, discrimination and bullying, and outlines the support available to employees.

ETHICS HOTLINE

The Company has established a confidential Ethics Hotline hosted by an independent external service provider. The Ethics Hotline is available to employees, contractors and third parties to report allegations of non-compliance with the Code of Conduct. The internal audit department (“Audit Services”) is responsible for administering the Ethics Hotline process and ensuring all reports are investigated by the Company. Audit Services provides an overview of the Ethics Hotline reports to the Audit Committee on a quarterly basis.

CORPORATE DISCLOSURE POLICY

The Board has approved a Disclosure Policy to ensure that communications to investors and potential investors are timely, factual and accurate, and that the information is disseminated in accordance with all applicable legal and regulatory requirements to the investing public, analysts and the media. For the full text of the Corporate Disclosure Policy, visit www.emera.com/governance.

CONFLICTS OF INTEREST

Directors are required to declare any conflict of interest which they may have in a matter before the Board. In any matter requiring approval of the Board, a Director is prohibited by the Company’s Articles of Association from voting in respect of the matter in which the Director is interested.

 

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RELATED PARTY TRANSACTIONS

Transactions between Emera and related parties are monitored in several ways to determine that such transactions comply with applicable laws, regulatory rules, and Emera’s Code of Conduct. In particular:

 

   

The Audit Committee oversees the disclosure in Emera’s financial statements of related party transactions that are required to be disclosed pursuant to United States Generally Accepted Accounting Principles. In the ordinary course of business, Emera provides energy, construction and other services and enters into transactions with its subsidiaries, associates and other related companies on terms similar to those offered to non-related parties. All material amounts are under normal interest and credit terms. Additional disclosure is provided in Emera’s financial statements regarding more significant transactions between Emera and its associated companies.

   

Under Emera’s Articles of Association, any Director who has an interest in a transaction with the Company must disclose the existence and nature of the interest to the Board of Directors and such director may not participate or vote on the matter.

   

Under Emera’s Code of Conduct, Directors, officers and employees of Emera cannot own more than a 10 per cent interest in, or act in the capacity of a director, officer, partner, consultant, employee or agent for a supplier, contractor, sub-contractor, Emera customer, competitor or any other person or organization with which Emera has a similar relationship, without the express prior approval of Emera’s President, Board Chair or its Board of Directors, as the case may be. They must also seek similar approval when a company, partnership or business in which they, or a member of their family, own more than a 10 per cent interest, or in which they are a director, partner, officer, consultant, employee or agent seeks to do business with Emera.

   

Also, as described in Emera’s Code of Conduct, Emera’s subsidiaries are regulated by several Canadian, U.S. and Caribbean energy regulators. Certain of these regulators have imposed specific codes and standards of conduct which address matters such as undue discrimination and preferential treatment between regulated companies and their affiliates. These rules may apply to and restrict arrangements between affiliates to conduct business or share employees. Emera’s subsidiaries have created separate codes and standards of conduct addressing these matters. Directors, officers and employees are required by the Code to be aware of, and comply with, these affiliate rules at all times.

The Audit Committee is responsible for annually receiving and reviewing a report on executive officers’ compliance with the Code of Conduct and receives quarterly reports on the Company’s ethics program, including reports received through the Ethics Hotline (see Ethics Hotline, above) or submitted directly to the Company’s Audit Services group.

SUBSIDIARY GOVERNANCE

The Tampa Electric Company and Nova Scotia Power Boards have each adopted Board charters. These charters reflect the appropriate balance between the role of an operating subsidiary Board and the role of Emera as the parent holding company. In 2020, the NCGC approved a form of a Board charter to be used as a model for adoption by each operating subsidiary Board that does not currently have a Board charter. Emera’s operating subsidiaries have robust and disciplined governance processes that include fully active Boards of Directors, with most having a complement of external Directors. In most cases, external, independent, and local Directors are added to the subsidiary Board until they form a majority on the Board. The inclusion of external members on subsidiary Boards in a fiduciary role as Directors has significant benefits. Local Directors bring a diversity of thought and perspective to the Board table and they bring a connection to the community where the business is located.

The Chair of each operating subsidiary Board is elected in accordance with the subsidiary’s organizational documents and is typically Emera’s CEO or an Emera executive based on the CEO’s recommendation. Additional Emera and subsidiary executives are also Directors but combined would typically form a minority of the Board. Emera values the benefits that diversity can bring to subsidiary Boards of Directors. Emera’s operating subsidiaries seek to achieve and maintain a Board comprised of talented and dedicated Directors with a diverse mix of experience, skills and backgrounds.

As the parent holding company, Emera provides certain corporate-wide services to its operating subsidiaries. These corporate- wide services, which provide benefit for the entire organization, include several areas such as safety, environment, compliance, internal audit, insurance, corporate security and treasury services. Enterprise-wide policies of Emera, such as Emera’s safety management system, are either expressly adopted by an operating subsidiary Board, or the impact is considered by Emera through consultation with the operating subsidiary.

 

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COMMITTEES OF THE BOARD OF DIRECTORS

The Board is committed to effectively and efficiently carrying out its oversight responsibilities. As such, it strongly supports the work of its four standing Committees, to which certain functions are delegated as set forth in the written charters. The Board Committees are:

 

  (a)

the Audit Committee;

 

  (b)

the Health, Safety and Environment Committee (“HSEC”);

 

  (c)

the Management Resources and Compensation Committee (“MRCC”); and

 

  (d)

the Nominating and Corporate Governance Committee (“NCGC”).

From time to time the Board establishes ad hoc Committees.

AUDIT COMMITTEE

The Audit Committee is comprised of:

Chair: Mr. Harvey

Members: Ms. Loewen, Ms. Rosen, Mr. Sergel and Mr. Tilk

The Audit Committee assists the Board in discharging its oversight responsibilities concerning the integrity of Emera’s financial statements, its internal control systems, the internal audit and assurance process, the external audit process and its compliance with legal and regulatory requirements.

The Committee consists of independent Directors only, who each have a high degree of financial acumen. The Committee is responsible for reviewing and recommending to the Board the annual and interim financial statements and all related management’s discussion and analysis.

The Committee evaluates and recommends to the Board the appointment of the external auditors and the compensation of such external auditors. Once appointed, the external auditors report directly to the Committee, and the Committee oversees the work of the external auditors concerning the preparation or issuance of the Auditors’ reports or the performance of other audit, review or at test services for Emera.

The Committee reviews and discusses Emera’s major financial risk exposures and the policy steps management has taken to monitor and control such exposures, including the use of financial derivatives, hedging activities, credit and trading risks, and cybersecurity.

The Committee reviews management controls and processes concerning the administration of investment activities, financial reporting, and financial performance and funding of the pension plans. The Company’s lead internal auditor also reports directly to the Audit Committee, and the Committee oversees the appointment, replacement and termination of the lead internal auditor.

For the full text of the Audit Committee Charter, visit www.emera.com/governance.

 

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HEALTH, SAFETY AND ENVIRONMENT COMMITTEE (“HSEC”)

The HSEC is comprised of:

Chair: Mr. Bertram

Members: Mr. Harvey, Ms. Loewen and Mr. Ramil

The HSEC consists of Directors selected by the Board. A majority of Committee members shall be independent Directors. The purpose of the HSEC is to assist the Board in carrying out its responsibilities relating to oversight and coordination of Emera’s health, safety and environmental programs, and making recommendations to the Board as appropriate.

The Committee’s role is to review the performance of the Company on health, safety and environmental matters, including the Company’s compliance with legislation, and conformance with industry standards and best practices. It reviews emergency response plans and programs.

The HSEC oversees the Company’s health, safety and environmental systems and policies. It reviews actions taken by the Company to identify and manage risks. This oversight extends to Emera’s subsidiaries.

Any significant safety or environmental incidents respecting the Company’s assets or operations will be reviewed by the HSEC, including those involving personnel safety, contractor safety, public safety or environmental damage. The Committee oversees management’s response to any significant regulatory findings, orders, reports and/or recommendations related to health, safety and the environment.

For the full text of the HSEC Charter, visit www.emera.com/governance.

MANAGEMENT RESOURCES AND COMPENSATION COMMITTEE (“MRCC”)

The MRCC is comprised of:

Chair: Ms. Chrominska

Members: Mr. Bertram, Mr. Demone and Mr. Tilk

The MRCC consists of independent Directors only. The Committee reviews overall compensation, including salary and benefits policies, and recommends such policies to the Board of Directors for approval.

The MRCC supports the Chair of the Board in conducting a review of corporate goals and objectives relevant to the President and CEO’s compensation and supports the Chair of the Board in recommending such goals and objectives for the current year to the Board of Directors. The Committee ensures that an assessment of the President and CEO’s performance in relation to these goals and objectives is completed. It makes recommendations to the Board of Directors relating to the President and CEO’s total compensation, including participation in incentive compensation and equity-based plans. It also makes recommendations about senior management’s total compensation and incentive compensation plans and equity-based plans. It approves grants of stock options, performance share units (“PSUs”), restricted share units (“RSUs”) and deferred share units (“DSUs”) in accordance with the provisions of the respective plans. It reviews executive compensation disclosure prior to the Company releasing such information to the public.

The Committee recommends executive officer appointments to the Board of Directors for approval. It supports and contributes to the Board’s succession planning process in respect of the President and CEO of the Company. It annually reviews the succession planning process for senior management and other potential senior management candidates, including for Emera’s subsidiaries, and oversees and contributes to that process. It reviews share ownership guidelines for executive officers. It satisfies itself that there are appropriate labour relations strategies in place and it regularly reviews management’s direction and decisions made in support of labour and employee relations. It also reviews the design of pension plans for the Company’s employees.

 

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The MRCC is responsible for evaluating the compensation programs to determine that they do not reward executive officers for taking inappropriate risks that may harm the interests of the Company and its shareholders. Under its Charter, the Committee must conduct a compensation risk review annually to ensure that the compensation policies are designed to take account of and mitigate:

 

  (a)

incentive opportunities that inadvertently encourage excessive and unnecessary risk-taking;

 

  (b)

pay structures that inadvertently encourage behaviour that negatively impacts long-term value;

 

  (c)

misalignment of pay and performance; and

 

  (d)

payouts which are not aligned with Emera’s business strategy.

For the full text of the MRCC Charter, visit www.emera.com/governance.

NOMINATING AND CORPORATE GOVERNANCE COMMITTEE (“NCGC”)

The NCGC is comprised of:

Chair: Ms. Rosen

Members: Mr. Demone and Mr. Sergel

The NCGC assists the Board with a variety of matters relating to corporate governance. One of its primary duties is to provide the Company with a list of nominees for election as Directors to be included in the Company’s Management Information Circular prior to each Annual Meeting of Shareholders of the Company. The Committee is responsible for identifying, considering and recruiting people qualified to become Directors, having regard for the background, employment and qualifications of possible candidates and the criteria for service as a Director as approved by the Committee and the Board. For more information about the nomination of Directors, see Nomination of Directors and Director Recruitment Process earlier in this Circular. The Committee consists of independent Directors only, selected by the Board.

The NCGC oversees the succession of Directors in accordance with the Board’s Renewal Principles and following a full skills assessment, having regard to the anticipated retirement of Directors and, where applicable, the Chair of the Board and Committee Chairs.

The NCGC is responsible for developing and communicating the Company’s approach to corporate governance issues, and reviews and approves Emera’s disclosure of corporate governance practices, including this Statement of Corporate Governance Practices. The Committee keeps abreast of best governance practice benchmarks and regularly evaluates the governance practices of Emera. It reviews any disclosure of the Company’s corporate governance practice in accordance with applicable rules and regulations.

The NCGC oversees the orientation of new Directors. This orientation program for new Directors is reviewed each time that a new Director joins the Board and is updated as required.

The Committee is responsible for assisting the Board of Directors in determining the proper and effective allocation of risk oversight responsibilities. Other duties and responsibilities of the Committee include:

 

  (a)

assisting the Board and its Committees in determining Committee composition, as well as reviewing and updating the mandate of each Committee, for submission to the Board;

 

  (b)

making recommendations to the Board on all components of non-employee Director compensation, including the Board Chair and Committee Chairs;

 

  (c)

ensuring procedures are in place to assist the Board in obtaining information necessary to carry out its duties and ensuring the Board has access to executive management;

 

  (d)

reviewing and updating the Company’s Code of Conduct;

 

  (e)

determining the process by which performance assessments are to be conducted, which evaluate the performance of the Board, the Board Chair, individual Directors, Board Committee Chairs and Board Committee members;

 

  (f)

reviewing all activity with respect to the indemnification of Directors and officers; and

 

  (g)

overseeing pension governance for the Emera group of companies.

For the full text of the NCGC Charter, visit www.emera.com/governance.

 

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COMMUNICATION WITH DIRECTORS AND SHAREHOLDER ENGAGEMENT

Disclosure Policy and Practices

The Board has adopted a Disclosure Policy to ensure all communications of material information to the investing public about the Company are accurate, that they fairly present in all material respects the Company’s financial condition and its results of operations and are made on a timely basis.

Emera has established an executive Disclosure Committee responsible for overseeing the Company’s disclosure practices. The Company’s CEO and CFO, the leaders of its businesses, and senior management responsible for legal, finance, investor relations, and communications functions are members of the Disclosure Committee, which meets at least quarterly. Members of the Committee are responsible for reviewing all core disclosure documents containing material information, including the Company’s management’s discussion and analysis and financial statements prior to their being presented to the Audit Committee and Board for approval. The Committee is responsible for taking reasonable measures to ensure the education of Directors, officers and employees about disclosure issues and the Disclosure Policy. The Disclosure Policy defines the Company’s designated spokespersons and outlines the role of employees in Company disclosure. It also defines procedures for contact with analysts, investors and the media and guidelines for the disclosure of forward-looking information in continuous disclosure documents, speeches and conference calls.

Emera’s Disclosure Policy may be found on its website at www.emera.com/governance.

Engagement

Emera has a mature and robust program of engaging with investors through meetings with shareholders, investor day events and other initiatives. In 2020, Emera’s executives met with many of the Company’s shareholders, including all of Emera’s active top 20 investors. An investor day is generally held each year, most recently on February 25, 2020 in Tampa, Florida. Directors receive detailed reports on the shareholder engagement activity by management at each regularly scheduled meeting of the Board.

The Directors are interested in shareholders’ views about the Company, its governance and its operations. The Board oversees systems for receiving feedback from shareholders and it monitors feedback received by the Company.

 

   
Shareholders are encouraged to provide feedback to management and/or the Board    Contact information
   
To reach management:     
   

• President and CEO

 

• Chief Financial Officer

 

• Chief Legal and Compliance Officer

 

• Corporate Secretary

   Email: Scott.Balfour@emera.com Email: Greg.Blunden@emera.com Email: Bruce.Marchand@emera.com Email: Stephen.Aftanas@emera.com
   
To reach the Board: (1)     
   

• Chair of the Board

 

• Chair of a Committee

   Email: info@emera.com

 

(1)  Confidential

communications with the Chair of the Board or another Board member should be mailed to the address below marked “Private and Confidential”.

The Board has engaged with the Canadian Coalition for Good Governance (“CCGG”), which represents a number of Canadian institutional shareholders (including many of Emera’s largest shareholders), in promoting good governance practices in Canadian public companies. In October 2017, Ms. Sheppard, the Board Chair, and Ms. Chrominska, the Chair of the MRCC, met with representatives of the CCGG in a Board engagement session. The purpose of the Board engagement meeting was to provide a private forum for dialogue and exchange of views between independent Directors and institutional investors. The Board engagement meeting was not attended by any member of Emera’s management. Following this Board engagement session, Emera was awarded the 2018 Governance Gavel Award recognizing excellence in shareholder communications as reflected in Emera’s Management Information Circular. The CCGG again reached out to schedule a further Board engagement meeting in June 2019. This further meeting was also attended by Ms. Sheppard as Board Chair and Ms. Chrominska as MRCC Chair. Again, no member of Emera’s management attended the meeting.

 

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The meeting’s discussion topics included Emera’s corporate governance practices and disclosure, executive compensation, Board oversight of risk and the Company’s approach to sustainability and ESG as an emerging focus area for institutional investors.

The Board recognizes that shareholder engagement is an evolving practice and plans to review its practices annually with a view to enhancing their effectiveness.

 

 

Shareholder engagement process   Contact information

Shareholders may communicate with the Chair of the Board or other independent Directors by sending them a letter using regular mail or other means of delivery. If the envelope is marked “Private and Confidential”, it will be delivered, unopened, to the Chair of the Board of Directors, or such other independent Director to whom it is addressed.

 

 

Attention: Chair of the Board of Directors of

Emera Inc. (or Name of Independent Director)

 

P.O. Box 910, Halifax, Nova Scotia B3J 2W5

 

in a sealed envelope marked “Private and Confidential”

Say on Pay

Emera’s 2021 Annual Meeting of Shareholders will again ask shareholders to consider and approve the Company’s approach to executive compensation. While the outcome of the vote is non-binding, the MRCC will take the results of the vote very seriously in determining the Company’s approach to executive compensation.

Shareholder Proposals

Shareholders can submit proposals to be considered at an annual meeting of the Company provided they are duly submitted in advance and included in the Management Information Circular for the meeting. A shareholder intending to submit a proposal for consideration at an annual meeting must comply with the applicable provisions of the Nova Scotia Companies Act and the Company’s Articles of Association (“Articles”). This includes compliance with the requirements for Director nominations contained in the Articles where the proposal includes a nomination for the election of an individual to the Board of Directors. The Company will include a shareholder proposal in its Management Information Circular prepared for an annual meeting provided such proposal was received by the Company at least 90 days before the anniversary date of the previous annual meeting and provided such proposal is required by the Companies Act to be included in such Management Information Circular. Regardless of whether you are submitting a proposal, the nomination of Directors is still subject to compliance with the Articles which require notice of the nomination not less than 30 days prior to the date of the annual meeting. Should you have any questions about shareholder proposals or Director nominations, please contact Emera’s Corporate Secretary using the contact information in the Notice of Meeting at the beginning of this Circular.

ADDITIONAL INFORMATION

Additional information relating to the Company may be found on the System for Electronic Document Analysis and Retrieval (“SEDAR”) at www.sedar.com. The Company’s financial information is contained in its comparative financial statements and management’s discussion and analysis for the financial year ended December 31, 2020.

For copies of the Company’s financial statements and management’s discussion and analysis, you may also contact the Office of the Corporate Secretary at:

Corporate Secretary

P.O. Box 910, Halifax, Nova Scotia B3J 2W5

Telephone: 902.428.6096; Facsimile: 902.428.6171; email: Stephen.Aftanas@emera.com.

 

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SENIOR MANAGEMENT STOCK OPTION PLAN AMENDMENT

At the Meeting, shareholders will be asked to ratify, confirm and approve, with or without variation, an amendment to the Senior Management Stock Option Plan (the “Plan”), under which options may be granted to senior management in respect of authorized and unissued common shares of the Company to a current maximum of 11,700,000 shares, or approximately 4.65 per cent of the total issued and outstanding common shares of the Company (all figures in this section are as of December 31, 2020 unless otherwise noted).

The Plan has been established by the Company as a long-term incentive program for senior management of the Company and its affiliates. This Plan is intended to: (a) encourage participants to acquire an increased proprietary interest in the Company and to thereby participate in the Company’s future growth and development; (b) attract and retain high calibre senior management; and (c) provide an incentive to further the development, growth and profitability of the Company, and thereby to enhance shareholder value.

The purpose of the amendment is to increase the maximum number of common shares available for issuance under the Plan by an additional 3,000,000 common shares issuable under the Plan, which represents approximately 1.19 per cent of the Company’s issued and outstanding common shares.

INCREASE MAXIMUM NUMBER OF SHARES

The common share reserve of 1,706,109 was originally approved by shareholders in April 1994. In May 2006 the reserve was increased to 6,700,000 common shares, and then in 2014, the reserve was further increased to the current maximum of 11,700,000 common shares. Since its inception in 1994, 8,170,108 common shares have been issued under the Plan, which represents approximately 3.25 per cent of the total issued and outstanding common shares of the Company, leaving 3,529,892 common shares reserved for issuance under the Plan.

Accordingly, the 3,529,892 common shares reserved for issuance under the Plan, together with the 3,000,000 additional common shares sought to be made available for issuance under the Plan by virtue of the proposed amendment, represent approximately 2.60 per cent of the total issued and outstanding common shares of the Company.

If this amendment is not approved, the inventory of common shares available for issuance under the Plan will be exhausted by the Company for the 2022 grants, and the Plan will no longer be available to encourage common share ownership. This increase will allow for a sufficient reserve balance to be maintained, based on granting an average of 550,000 options per year, for the next five years.

For more information about the Plan, see the section entitled Senior Management Stock Option Plan in the Statement of Executive Compensation later in this Circular.

SHAREHOLDER APPROVAL

The rules of the TSX require that the above-described amendment to the Plan be approved by an ordinary resolution passed by a majority of the votes cast by holders of common shares present or represented by proxy at the Meeting. The management representatives designated in the enclosed form of proxy intend to vote FOR the ratification, confirmation and approval of the amendment to the Plan. The full text of the amendment is set out in the resolution attached as Appendix “B” to this Circular.

RECOMMENDATION OF DIRECTORS

The Board believes that the proposed amendment is in the best interests of the Company and unanimously recommends that shareholders vote in favour of the proposed amendment by voting FOR the resolution set out in Appendix “B” to this Circular.

 

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A LETTER FROM THE MANAGEMENT RESOURCES AND COMPENSATION COMMITTEE TO OUR SHAREHOLDERS

Dear Shareholder:

At Emera, our commitment to delivering sustainable value to shareholders is rooted in the strength of our strategy, portfolio and team. The ability of our executive team to lead and motivate all employees to act in the best interests of shareholders, customers and other stakeholders is fundamental to that commitment to shareholders. This was particularly evident in 2020 as our executive leaders established new policies and procedures to guide our teams through the global COVID-19 pandemic and continue to deliver the energy our customers count on and the value our shareholders expect.

Emera’s compensation philosophy is to align pay with performance. This is why we directly link a significant portion of the compensation we pay our executives to the achievement of objectives that drive value. We believe that aligning the interests of our executives with the interests of our shareholders is critical so we require executives to hold significant equity in the Company. Our share ownership guidelines reflect our belief that executives must also be shareholders and maintain a meaningful personal financial stake in the Company.

The Management Resources and Compensation Committee (the “Committee” or “MRCC”) is the steward of the Company’s compensation programs and oversees all aspects of executive compensation. The Committee carefully assesses and makes recommendations to the Board on how performance measures and targets are set so they reflect the Company’s core values and our short- and long-term strategic priorities. The targets must be achieved within the principles of prudent risk management, good corporate governance, and compliance with relevant standards and regulations. Guided by these principles and input from other members of the Board, the Committee diligently oversees the establishment of the Company’s performance goals and assesses our executive compensation programs, including payouts for the executive team, while continuously seeking to improve our practices and standards.

We are pleased to provide an overview of our approach to executive compensation, the Board’s assessment of Emera’s 2020 performance, and our decisions relating to executive compensation.

COVID-19 IMPACT

Despite the challenges of COVID-19, the Committee felt that the existing compensation policies adequately addressed the impact of the pandemic and, consequently, no changes have been made to Emera’s short- and long-term incentive measures, targets or payouts in 2020.

SAY ON PAY

We held our annual “Say on Pay” advisory vote at our 2020 Annual Meeting that allowed shareholders to indicate whether they agreed with Emera’s compensation practices and policies. Shareholders voted 99.13 per cent in favour of our approach to executive compensation, an increase in support over the 2019 results. At this year’s Annual Meeting of Shareholders, we will again be presenting a “Say on Pay” non-binding advisory resolution. As part of our continued commitment to shareholder engagement, it is important for us to receive direct feedback from our shareholders and have constructive dialogue about our compensation decisions and other governance matters. Shareholders can contact the Chair of the Committee or the Chair of the Board at the address listed at the end of this letter.

2020 COMPENSATION DECISIONS

Based on the comparative positioning of Emera’s target compensation to market, the Committee is satisfied that our named executive officers are compensated competitively and aligned with our overall compensation philosophy.

Our compensation philosophy is guided by the median level of compensation paid by our peer group, which is made up of companies of a similar size, scope and complexity as Emera. In addition to the market competitive data, the Committee considers experiences, uniqueness of responsibilities and performance of the Named Executive Officers (“NEOs”) in setting the level of target compensation. At the end of 2020, the Committee reviewed benchmarking analyses from both Hugessen Consulting Inc., the Board’s independent compensation advisor, and Mercer (Canada) Limited, management’s external compensation advisor, using the Company’s benchmarking comparator group. The Committee will continue to monitor market trends to maintain our competitive positioning.

 

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In 2020 the Committee conducted a review of the components of the Company’s long-term incentive plan to assess the plan’s effectiveness and measure how Emera compared to its peers and the general market. Stemming from this review, the Committee approved the creation of a Restricted Share Unit (“RSU”) Plan, which came into effect in 2020. Emera’s most senior executives, including all NEOs, now receive 25 per cent of their long-term incentive grant value in the form of RSUs, while other long-term incentive plan recipients received 50 per cent in RSUs. These changes increase the effectiveness of the plan and the alignment with market practice and will act as a retention tool for the Company, particularly at levels below the senior executive level, while still maintaining a significant at-risk proportion of total compensation. More information on these plan changes can be found in Long-term Incentive Program.

The Committee also approved changes to the Company’s Employee Common Share Purchase Plan to enhance alignment to market and encourage employees broadly across Emera to become shareholders, which will further align interests between shareholders and employees. The changes are described in more detail in Changes to the Employee Common Share Purchase Plan that took effect in 2020.

The Committee also conducted its annual risk assessment to identify potential risks associated with Emera’s compensation design and policies, including risks associated with the changes to the long-term incentive plans noted above. The assessment concluded that there are no material risks associated with the compensation programs and the Company has an appropriate system of checks and balances in place to mitigate the level of risk undertaken by management. The Committee will continue to diligently monitor our programs to maintain our high governance standards.

REWARDING RESULTS

Emera’s achievements, as referenced throughout, have resulted in Emera delivering a consistent return on investment to shareholders in 2020 and historically over the longer term, which is indicated in the charts below. Emera’s total shareholder return (“TSR”) in 2020 was 1 per cent. On a cumulative basis, Emera’s TSR is 33 per cent over the past three years and 58 per cent over the past five years, which underperformed compared to the TSR of the S&P/TSX Capped Utilities Index but exceeded the S&P/TSX Composite Index over the same time frames. Over the past three and five years, Emera has delivered a 10 per cent return to shareholders on an annualized basis.

 

LOGO    LOGO

 

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Recognizing Emera’s performance against objectives established for the 2020 Emera Corporate Scorecard, the Board approved an annual Short-term Incentive Plan payout of 142 per cent of target for the Named Executive Officers. A full description of the 2020 Scorecard metrics and results is provided in 2020 Short-term Incentive Results.

Our 2020 Long-term Incentive Plan, which consisted of performance share units (“PSUs”), restricted share units (“RSUs”), and stock options, is also closely aligned with our performance objectives. PSUs are linked to performance metrics that are measured over a three-year period. The 2018 PSU grant, which had a performance period from January 1, 2018 to December 31, 2020, measured Emera’s growth in earnings per share and cash flow from operations. Emera’s earnings per share growth fell slightly short of target, but growth in cash flow from operations was strong, which led to a performance factor of 112 per cent. Our long-term incentives are also linked to Emera’s share price.

The Committee carefully reviews the metrics chosen for our incentive plans each year to ensure they continue to reflect the Company’s key strategic objectives.

The Committee engaged Hugessen Consulting Inc. to conduct the annual pay-for-performance analysis of the compensation paid to the President and CEO. The review looked at the compensation paid to former President and CEO Chris Huskilson from January 2011 to December 2017, and the compensation paid to Mr. Balfour from 2018 to 2020, and compared the investment returns experienced by shareholders over those same periods. The analysis included both realized pay (consisting of amounts paid) and realizable pay (consisting of the value of any outstanding equity-based awards). The analysis concluded there was appropriate alignment between the President and CEO’s realized/realizable pay and shareholders’ investment return experience over the long term. Please see Total Shareholder Return vs. Named Executive Officer Compensation for more information on the analysis.

Based on the Company’s performance in 2020 and the impact of that performance on the compensation we pay our executives, we remain confident that our incentive plans and resulting payouts are closely aligned with the interests of our shareholders.

SUSTAINING SHAREHOLDER VALUE

The accomplishments of the team in 2020 are significant and outlined throughout this document. The strength and stability of Emera are due in large part to the performance of the executive team.

We remain confident that our executive compensation programs reflect our values and work well to retain and motivate executives to perform and deliver for customers and shareholders. We will continue to monitor our practices and industry trends and adjust our practices accordingly.

As always, we welcome your review of our compensation programs and results, which are described in more detail in the Statement of Executive Compensation that follows. We encourage you to take part in our “Say on Pay” vote and we welcome your questions and feedback, which can be provided directly to the Chair of the Committee or the Chair of the Board by mailing (through regular mail or other means of delivery) to:

 

Attention: Chair of the MRCC,    Attention: Chair of the Board,
P.O. Box 910, Halifax, Nova Scotia B3J 2W5    P.O. Box 910, Halifax, Nova Scotia B3J 2W5
in a sealed envelope marked “Private and Confidential –    in a sealed envelope marked “Private and Confidential –
Attention, Chair of the MRCC of Emera Inc.”    Attention: Chair of the Board of Directors of Emera Inc.”

 

Sylvia Chrominska    James Bertram    Henry Demone    Jochen Tilk
Director and Chair of the    Director and Member of the    Director and Member of the    Director and Member of the
Management Resources and    Management Resources and    Management Resources and    Management Resources and
Compensation Committee    Compensation Committee    Compensation Committee    Compensation Committee

 

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STATEMENT OF EXECUTIVE COMPENSATION

COMPENSATION PHILOSOPHY

The purpose of Emera’s executive compensation program is to:

 

   

align the interests of executives with the interests of Emera’s shareholders and customers.

 

   

attract, retain and motivate highly qualified and high-performing executives; and

 

   

reward Emera’s executives for sustained growth in shareholder value.

The program includes both short- and long-term incentive plans that are designed to reflect the Company’s pay-for-performance philosophy and to provide for a significant portion of an executive’s compensation to be at risk, while aligning the structure of programs and payouts with sound risk management and good governance principles.

MARKET COMPETITIVENESS

Emera benchmarks the compensation it pays its executives to ensure the Company pays competitively in the markets where it operates, and to motivate, attract and retain high-quality talent. Emera’s executive compensation program is designed to generally provide total target compensation at the median of compensation paid by comparable companies whose operations are of a similar size and complexity as Emera. Pay positioning, in some specific cases, may be above or below the median based on experience, uniqueness of responsibilities and performance. “Total target compensation” for senior management, including the named executive officers, is comprised of base salary, target short-term incentive and target long-term incentives linked to creating shareholder value.

PAY-FOR-PERFORMANCE

A core principle of Emera’s executive compensation philosophy is that a significant portion of executive compensation is at risk and linked to the achievement of objectives that measure whether shareholders are experiencing strong return for their investment. The at-risk components include both short- and long-term incentives, which establish measurable financial, organizational, safety and environment objectives that, if achieved, add value to the Company.

The incentive compensation plans are designed to pay greater amounts for superior performance and lesser amounts if target performance is not achieved. The Company must achieve a threshold level of performance for any payment against a particular objective, failing which there is no payment against that objective. Executives’ performance against those objectives is measured and rated by the President and CEO with a recommendation to the MRCC, which in turn discusses the assessments with the Board of Directors for approval. The Board Chair, in collaboration with the MRCC and the Board as a whole, assesses the performance of the President and CEO.

Generally, the at-risk compensation component of total compensation increases in conjunction with the individual executive’s level of responsibility. The Company considers many factors when developing the incentive plans, including current compensation trends, plan costs (including maximum payout values), expected value to be delivered to participants and analysis of threshold, target and stretch payouts. Both short- and long-term incentive plan designs are modelled using historical and prospective performance scenarios. This stress testing provides the MRCC and the Board with reasonable assurance that the plan payouts will be appropriate and aligned with shareholder and Company objectives. The Company conducts analyses every year to determine how actual payouts compare to expected payouts and whether the plan components and design require any changes.

The MRCC and Board reserve the right to exercise discretion in adjusting compensation payouts to align with Company results, which may include refraining from paying out any amounts under the incentive compensation plans where circumstances warrant.

The MRCC has previously approved a set of guiding principles to govern when discretion is applied to ensure consistency and fairness when adjustments are made to incentive compensation.

 

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COMPENSATION PROGRAM

Emera’s compensation program includes the following components, which are discussed further in the pages noted:

 

 
Base Salary (page 65): Salaries are benchmarked against companies of similar size and scope as Emera or the respective affiliate and are set to reflect the degree of special skills and knowledge required now and in the future for the position and the performance and contribution of the individual.
 
Short-term Incentive Program (page 65): Short-term incentive objectives are set forth in scorecards and consist of key annual objectives linked to the Company’s corporate strategy. These scorecards establish measurable financial, organizational, safety and environment objectives that, if achieved, are designed to add value to the Company.
 
Long-term Incentive Program (page 70): Consists of performance share units (“PSUs”), Restricted Share Units (“RSUs”) and stock options. Levels are determined based on competitive benchmarking data and the degree of the executive’s responsibility within the Company. They are intended to align executive performance with a long-term focus on creating and preserving shareholder value.
 
Pension Plan Benefits (page 81): The Pension Plan consists of either defined benefit or defined contribution components and a supplemental employee retirement plan, all of which are governed by a pension oversight governance framework.
 
Other Executive Benefits (page 88): The Company also offers market competitive non-cash compensation components such as group benefits, vacation, wellness incentives and an Employee Common Share Purchase Plan.

MANAGEMENT RESOURCES AND COMPENSATION COMMITTEE

The Board has assigned responsibility to the MRCC to review, recommend and oversee the determination of the compensation for Emera’s executive officers and the administration of all the Company’s executive compensation plans and programs. Current members of the MRCC are:

 

   

Ms. Sylvia Chrominska (Chair);

   

Mr. James Bertram;

   

Mr. Henry Demone; and

   

Mr. Jochen Tilk.

All members of the MRCC are independent Directors. Each member of the MRCC has experience with human resources issues and compensation matters. More detailed information on each member’s qualifications and experience is contained in Director Nominees.

 

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The MRCC considers best practices in determining and monitoring executive compensation as discussed in this Circular. Our key practices, which we believe promote good governance and serve the interests of our shareholders, are summarized below:

 

 
What we do
 
Outline the Company’s approach to executive compensation through the MRCC’s Letter to Shareholders.
 
Provide shareholders with the opportunity to vote on a “Say on Pay” resolution at the Company’s Annual Meeting, which allows shareholders to indicate whether they are in agreement with Emera’s compensation practices and policies (99.13 per cent of votes cast last year were in favour of the Company’s approach).
 
Align the Company’s compensation programs with its corporate strategy through the use of financial and non-financial performance metrics that support both short- and long-term strategic goals.
 
Perform an annual risk assessment to identify risks associated with our pay structure.
 
Retain an independent compensation advisor for the MRCC that does not provide any services directly to management.
 
Allow for the reduction or withholding of payouts under the short-term and equity-based incentive plans for results below expectations, at the MRCC and Board’s discretion.
 
Use double-trigger change of control agreements
 
Test compensation awards for appropriate alignment between pay and performance under a number of different outcome scenarios.
 
Provide detailed information on those companies used in the Company’s comparator group for benchmarking purposes.
 
Align executive pay with shareholders’ interests by having a significant component at risk and tied to both short- and long-term performance.
 
Have significant share ownership requirements in place for NEOs, which include a one-year post-retirement hold period.
 
Defer a substantial portion of long-term incentives for the majority of the senior executives and for other employees whose actions may have a material impact on the Company’s risk profile to discourage the taking of short-term or excessive risks.
 
Conduct pay equity analyses to help ensure the Company’s hiring and pay practices promote gender equality.
 
Have a pension oversight governance framework in place for pension benefits.
 
Monitor the ratio of the Company’s NEOs’ total compensation to the average employee’s total compensation.
 
Have a clawback policy that allows the Company to recoup short- and long-term incentive payments made to senior executives.
 
Disclose a lookback table showing how much the President and CEO has received in compensation over the past 10 years, factoring in long-term incentive payouts and changes in value.
 

Translate USD earnings to CAD earnings using a budgeted foreign exchange rate to ensure that fluctuations in the

foreign exchange rate do not positively or negatively impact the measurement of the Company’s performance results against its targets.

 
Conduct an extensive succession planning process where successor readiness over one, three, and five years is reviewed.
 
What we don’t do
 
Allow for the repricing or backdating of stock options.
 
Use single-trigger change of control agreements.
 
Allow the payment of dividends on share awards prior to vesting.
 
Count unvested awards that are subject to performance criteria, or unexercised stock options toward share ownership requirements.
 
Allow executives to limit their economic risk with respect to any Emera securities they hold through hedging, pledging or other such transactions.
 
Grant additional years of credited service to NEOs under the Company’s pension plan or supplemental employee retirement plan.
 
Compensate executives for sitting on or chairing the Boards of subsidiaries of the Company.

 

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COMMITTEE GOVERNANCE

The MRCC is responsible for reviewing the alignment of Emera’s compensation programs, including incentive pay programs, with Emera’s strategic plans, performance and risk management principles. The Committee annually reviews compensation for the President and CEO and senior management of the Company. The MRCC oversees the administration of the incentive plans providing for the award of short-term incentives, stock options, PSUs, RSUs and deferred share units (“DSUs”) in accordance with the provisions of the respective plans.

The Committee reviews, and recommends to the Board of Directors, compensation policies and processes, any new incentive and the equity compensation plans and any changes to such plans.

The Board Chair specifically discusses the President and CEO’s performance with each Director individually and provides feedback to the MRCC, the Board and the President and CEO on at least an annual basis. In addition, the CEO reports, and the Committee reviews, the progress toward annual objectives at every Board meeting.

RISK MANAGEMENT AND COMPENSATION

As part of the Board and MRCC’s oversight responsibilities for the design and administration of the Company’s executive compensation programs, the MRCC identifies and discusses design features or processes that may potentially represent conflicts of interest or inducements for unnecessary or excessive risk-taking by senior executives.

The MRCC also regularly monitors industry trends with respect to risk management and conducts an annual risk assessment in consultation with an external compensation consultant. Emera’s compensation programs and policies are designed to incorporate the Company’s view on appropriate risk, as demonstrated by the elements shown below, which are discussed in greater detail in the sections that follow:

 

 
The Company regularly reviews its executive compensation programs with third-party compensation advisors to confirm the programs continue to align with shareholder and stakeholder interests, comply with regulatory requirements, and are consistent with sound principles of risk management and governance. The MRCC retains an independent compensation advisor that does not provide any services directly to management.
 
The Company has a pay-for-performance philosophy and the mix of short- and long-term programs assists in mitigating excessive risk-taking.
 
Vesting requirements, stress testing of potential payouts, clawback provisions, an anti-hedging policy and share ownership requirements are part of the Company’s overall plan design to mitigate risk.
 
The Company’s compensation governance structure involves the Board, the MRCC, the MRCC’s external compensation advisor, management and management’s external compensation advisors.
 
All members of the MRCC are knowledgeable individuals who have the necessary background and expertise in human resources issues and compensation matters to fulfil their obligations to the Board and to shareholders.

 

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ANNUAL COMPENSATION RISK ASSESSMENT

In 2020, the MRCC conducted its annual compensation risk review of its executive compensation programs and policies. To assist in the review, management engaged Mercer (Canada) Limited (“Mercer”) to evaluate the previous year’s comprehensive risk assessment that Mercer conducted for any material changes over the course of the year. Mercer again concluded that Emera has risk mitigation policies in place that are aligned with market best practices and did not identify any material risks arising from Emera’s compensation policies and practices. Based on this assessment, the MRCC determined that:

 

   

Total compensation is appropriately balanced between short- and long-term horizons, and the mix of base salary and short- and long-term incentives does not create an inducement to take inappropriate risk to the detriment of the Company’s shareholders;

   

The use of multiple performance measures in the incentive plans (including non-financial measures) helps to avoid undue focus on any one particular metric;

   

The Short-term Incentive Plan focuses on growth of annual earnings and cash flow, but caps incentive payouts in a manner consistent with market practice, thereby reducing risk;

   

Risks associated with the Long-term Incentive Plan are mitigated by annual grants (versus front-loading grants) of PSUs, RSUs and stock options;

   

The MRCC and Board’s discretion to reduce or withhold payment under the short-term and equity-based incentive plans for results below expectations decreases the risks associated with those plans;

   

Emera’s executive share ownership requirements decrease risk in the compensation program by encouraging alignment between the interests of senior officers and the interests of shareholders. In addition, the Company’s anti-hedging policy helps maintain that alignment by prohibiting senior officers from reducing their economic risk with respect to any Emera securities they hold through hedging, pledging or other such transactions. The ownership requirement includes a one-year hold period post-retirement for NEOs;

   

The vesting conditions on retirement are an important retention tool for designated executives of the Company;

   

The clawback policy contributes to the Company’s risk mitigation efforts. The clawback policy allows the Company to recoup short- and long-term incentive payments made to senior executives in cases where: (a) the payments were based on reported financial results that were subsequently corrected or restated as a result (or partial result) of the executive’s gross negligence, misconduct or fraud and the reward received would have been lower had the financial results been properly reported; or (b) the executive commits a serious breach of the Company’s Code of Conduct; and

   

The inclusion of double-trigger provisions in senior executives’ employment contracts and the absence of enhanced benefits in a change of control mitigates the risk arising from a change in control of the Company.

Accordingly, based on the governance practices in place and the results of the risk assessment, the MRCC concluded that Emera’s compensation programs do not pose a material risk to the Company because an appropriate system of checks and balances is in place to mitigate the level of risk undertaken by management. The MRCC satisfies itself as to the adequacy of the information it receives regarding risk, the independence of the risk assessment, and the reporting of financial results on which certain important compensation decisions (such as incentive payouts) are based.

The MRCC and Board will continue to review the relationship between enterprise risk and the Company’s executive compensation plans and policies to confirm they continue to be optimally aligned with shareholder interests while maintaining an acceptable level of risk exposure.

 

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SUCCESSION PLANNING AND LEADERSHIP DEVELOPMENT

The MRCC assists the Board in the succession planning process for the President and CEO and has responsibility for overseeing succession planning for senior management of the Company and its affiliates. At Emera, succession planning is a dynamic, ongoing process of identifying, assessing and developing leadership competencies and business skills. The purpose is to confirm the Company’s capacity to meet future strategic objectives and to replenish critical organizational roles over time. The Board and Committee undertake this process on an annual basis. The Board also has responsibility for approving the appointment of the Company’s officers.

As part of the comprehensive succession planning process at Emera, the President and CEO annually provides a list of potential successors for his position to the MRCC. In addition, the President and CEO identifies internal successors for each of the NEOs and senior management positions throughout the Company and its affiliates. The Committee oversees the management succession planning process and developmental strategy, which includes assessments of the senior leadership at all affiliates to leverage the entire talent pool across Emera. The Board receives a related progress report from the CEO at every Board meeting during the in-camera session. In addition, the process also involves an annual discussion between the Chair and every member of the Board.

The succession planning process includes the identification of successors for all executive roles on a temporary or emergency basis in the event of an unexpected vacancy. This will help ensure that any impact on the Company’s operations is minimized until such time that a permanent successor is in place.

The Company’s leadership competencies model is aligned with our business strategy and connected to our values, as articulated in our Code of Conduct. These leadership competencies support our people in delivering results in a way that demonstrates Emera’s commitment to customers, shareholders, communities and each other. Our leadership competencies require our people to:

1.   Speak up on safety, health and the environment

2.   Take ownership and act with integrity

3.   Drive operational excellence for customers

4.   Build strong, collaborative relationships

5.   Develop people and teams

6.   Cultivate innovation and embrace change

7.   Think strategically and exercise sound judgment

These leadership competencies apply not only to management employees, but to every employee in the Company and every affiliate. The alignment of all employees to a common set of competencies provides the foundation from which we develop our people.

Emera is committed to developing leaders at all levels and has a comprehensive annual assessment process and framework to coordinate leadership development across the Company. This assessment process identifies areas of development for individuals as well as the leadership team with regard to identified core leadership capabilities. Personal development plans and overall Company leadership development programs, which reflect the above competencies, are in place for both existing and potential leaders. The Company focuses on ensuring challenging work assignments are offered, secondments to affiliates are made where appropriate, regular leadership development training occurs, and mentors are assigned where beneficial.

Emera will continue these focused efforts to build leadership capacity throughout the organization in support of its long-term growth strategy.

 

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COMPENSATION ADVISORS

The MRCC retains the services of independent compensation advisors to assist in discharging its duties, including determining the compensation payable to the President and CEO and other senior officers.

Since 2007, the MRCC has engaged Hugessen Consulting Inc. (“Hugessen”) as its principal advisor to provide independent advice, compensation analysis and other information for compensation recommendations. Hugessen provides advice on the competitiveness and appropriateness of compensation practices and comparator groups for Emera and its affiliates. In addition, Hugessen advises the MRCC on policy recommendations made by management, and also reviews and provides commentary on the Company’s Statement of Executive Compensation. As independent advisors to the MRCC, Hugessen does not provide any professional services to management.

The MRCC has adopted a number of practices with regard to its executive compensation advisor:

 

   

The MRCC annually reviews its advisor’s performance and fees.

   

With input from Company management and the advisor, the MRCC annually, or on an as-needed basis, determines the specific work the advisor is to undertake and the fees associated with this work.

   

Prior to undertaking any work, the MRCC’s advisor must provide an outline of the scope of work and related fees, and the MRCC Chair must provide written pre-approval.

   

The MRCC does not approve any work that, in its view, could compromise the advisor’s independence in serving the MRCC.

In addition to the MRCC’s compensation advisor, Emera engaged the services of Mercer and Morneau Shepell in 2020 to assist in executive compensation matters.

In making its decisions on the compensation program, the MRCC reviews information and recommendations provided by Hugessen, Mercer and Morneau Shepell, but all decisions remain the responsibility of the MRCC and the Board.

The table below summarizes the fees paid to all external compensation advisors in 2019 and 2020.

 

               2020                   2019    
Advisor      MRCC work ($)       Other work ($) (1)       MRCC work ($)       Other work ($)    

Hugessen Consulting Inc.

     148,360       Nil          137,329       Nil    

Morneau Shepell

     Nil       128,385          Nil       74,655    

Mercer (Canada) Limited

     Nil       114,290          Nil       183,100    

 

(1)

Mercer (Canada) Limited was retained by the Nominating and Corporate Governance Committee in 2019 and 2020 to review Directors’ compensation; the fees for that review are included in the amount shown.

 

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COMPENSATION DISCUSSION AND ANALYSIS

NAMED EXECUTIVE OFFICER COMPENSATION

The NEOs whose compensation is disclosed in this Compensation Discussion and Analysis are the President and CEO, the CFO and the next three most highly compensated executive officers of the Company, or its subsidiaries, as defined by Canadian securities legislation:

 

   

Scott Balfour, President and Chief Executive Officer, Emera Inc. (“President and CEO”);

   

Greg Blunden, Chief Financial Officer, Emera Inc. (“CFO”);

   

Nancy Tower, President and Chief Executive Officer, Tampa Electric Company;

   

Robert Bennett, President and Chief Executive Officer, Emera Technologies LLC; and

   

Bruce Marchand, Chief Legal and Compliance Officer, Emera Inc.

Scott Balfour, President and Chief Executive Officer, Emera Inc.

In March of 2018, Mr. Balfour was appointed President and CEO of Emera Inc. He serves as Chair of the Boards of Tampa Electric Company and Nova Scotia Power Inc. Despite the challenges, demands and impacts of a global COVID-19 pandemic, 2020 was a year of strong performance, both financially and operationally for Emera. Under his leadership, Emera’s safety culture and performance metrics showed measurable improvement, strategic planning efforts were both advanced and sharpened, Emera’s largest ever capital investment program was successfully executed, ESG positioning was strengthened including the establishment of forward-looking carbon reduction and coal closure goals, and he led the team to completion of the portfolio optimization plan with the closing of the Emera Maine transaction. Prior to his current role, Mr. Balfour served as Chief Operating Officer and Chief Financial Officer at Emera.

Greg Blunden, Chief Financial Officer, Emera Inc.

Mr. Blunden became CFO in 2016 and has accountability for financial leadership across Emera. In 2020, Mr. Blunden made substantial progress on Emera’s capital investment funding plan and supported the completion of the transaction to divest of Emera Maine. In addition, he led the relationship with capital market stakeholders and was instrumental in the development of the rate case strategy for key affiliates. Mr. Blunden is a Fellow Chartered Professional Accountant and has previously served in a number of financial, business development and strategy roles at Emera and its affiliates.

Nancy Tower, President and Chief Executive Officer, Tampa Electric Company

Ms. Tower was appointed to lead Emera’s largest affiliate in 2017 when she began overseeing Tampa Electric’s business strategy and operations. She led significant operational accomplishments in 2020 including achieving Tampa Electric’s best ever OSHA incident rate, best ever customer experience scores including top quartile JD Power scores, and record performance on reliability. In addition, her team advanced a number of important capital projects, including the Big Bend modernization project and completion of the final tranche of the 600 megawatt solar construction, without any negative impacts to budget or schedule despite any incremental challenges from the pandemic. Tampa Electric also reported outstanding financial performance with strong year over year earnings improvement. Ms. Tower is a Fellow Chartered Accountant and is scheduled to retire in 2021.

Robert Bennett, President and Chief Executive Officer, Emera Technologies LLC

Mr. Bennett was appointed President and CEO of Emera Technologies LLC (“ETL”) in 2018, an organization formed to focus on innovation, capitalize on business opportunities outside our regulated businesses and develop new technologies to position Emera as a dominant player in an evolving energy landscape. In 2020, ETL made good progress in the development of its proprietary direct-current microgrid system (“BlockEnergy”), with continued successful operation of the demonstration project at Kirkland Airforce Base, and the start of construction of the first pilot project in Florida in partnership with Lennar Homes and Tampa Electric. He is advancing discussions with other utilities and residential developers for more pilot projects in other regions, and he is also further advancing the BlockEnergy technology and securing related patent protections in anticipation of broader commercialization. Mr. Bennett also serves as a Director on the Boards of Tampa Electric Company and New Mexico Gas Company.

 

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Bruce Marchand, Chief Legal and Compliance Officer, Emera Inc.

Mr. Marchand leads a broad area of responsibility which includes Legal, Compliance, Internal Audit, Insurance, Corporate Secretary and Corporate Security. In 2020, in addition to his leadership of legal, internal audit and corporate insurance activities across Emera, Mr. Marchand assumed additional new responsibilities including the regulatory strategy and advanced the enterprise risk management analysis and enhanced the reporting on regulatory matters. He also supported the closing of the transaction to divest of Emera Maine.

The total target compensation for each NEO in 2020 is outlined below:

 

Name      Base salary ($)       

Short-term

incentive at target

(% of base salary)

 

 

 

    

Short-term

incentive at target

($)

 

 

 

    

Long-term

incentive at target

(% of base salary)

 

 

 

    

Long-term

incentive at target

($)

 

 

 

    
Total target
compensation ($)
 
 

Scott Balfour

     1,000,000        100        1,000,000        500        5,000,000        7,000,000  

Greg Blunden

     560,000        70        392,000        180        1,008,000        1,960,000  

Nancy Tower

     625,000        70        437,500        150        937,500        2,000,000  

Robert Bennett (1)

     637,213        60        382,328        125        796,516        1,816,056  

Bruce Marchand

     510,000        60        306,000        160        816,000        1,632,000  

 

(1)

Mr. Bennett is paid in USD. His base salary in 2020 was $475,000 USD, his short-term incentive target was $285,000 USD and his long-term incentive target was $593,750 USD. The figures shown for him in the table above have been converted to CAD using the exchange rate of $1.00 USD = $1.3415 CAD, which is based on the Bank of Canada daily average exchange rate between CAD and USD for 2020.

The following charts show the percentage weighting of each component of the total target compensation for the NEOs. In keeping with the Company’s pay-for-performance philosophy, the 2020 compensation plan design resulted in 86 per cent at-risk pay for our CEO and an average for the five NEOs of 72 per cent.

 

LOGO

Figures in charts have been rounded to the nearest percentage.

 

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COMPENSATION PROCESS

Benchmarking Data

The MRCC is responsible for annually reviewing the composition and use of comparator groups to assist in determining the compensation recommendations for the Company’s senior officers, including the President and CEO and other NEOs; the recommendations are then brought to the Board for approval. The MRCC undertakes periodic reviews of compensation design and total compensation opportunities for the senior management team, which helps ensure the programs are current and that they are fair comparisons for particular roles, recognizing varying responsibility and scope of executive positions within Emera and its affiliates.

Emera management engages the services of Mercer, an external compensation advisor, to compile market information on senior management compensation relating to base salary, and short- and long-term incentives. The MRCC also uses its independent compensation advisor, Hugessen, to assist in providing benchmarking data and advice when setting executive compensation levels and making changes to the Company’s compensation programs.

A complete benchmarking review takes place at least every two years and the scope of services includes competitive market reviews of senior executive compensation levels; review and observations of current executive compensation philosophy, policies and practices; and a review of pay and performance comparators.

The Company’s comparator group for senior executives consists of two sub-groups: (1) a Canadian group made up of companies in the Canadian energy, utility and general industry sectors; and (2) a US group made up of US energy and utility companies. It consists of the following companies:

 

 

Canadian comparators

 

  

 

US comparators

 

 

Energy & Utility Industry

Fortis Inc.

Hydro One Ltd.

ATCO Ltd.

TransAlta Corp.

TC Energy Corp.

Pembina Pipeline Corp.

Inter Pipeline Ltd.

AltaGas Ltd.

Algonquin Power & Utilities Corp.

Keyera Corp.

 

General Industry

Rogers Communications Inc.

Loblaw Companies Ltd.

Restaurant Brands International LP

TELUS Corp.

Nutrien Ltd.

Canadian Tire Corp. Ltd.

Air Canada

Canadian Pacific Railway

 

  

 

Energy & Utility Industry

Sempra Energy

WEC Energy Group, Inc.

Eversource Energy

DTE Energy Company

CMS Energy Corp.

Ameren Corp.

CenterPoint Energy, Inc.

NiSource Inc.

Alliant Energy Corp.

Pinnacle West Capital Corp.

UGI Corp.

Evergy, Inc.

Atmos Energy Corp.

OGE Energy Corp.

Black Hills Corporation

Avangrid Inc.

The inclusion of US companies reflects that approximately 73 per cent of the Company’s assets are now US-based and approximately 64 per cent of the Company’s revenues came from US operations in 2020. It also factors in the talent market for the executive team and the fact that most of Emera’s executives have significant oversight over US operations. While the benchmarking group assists in determining the appropriate compensation ranges for base salaries, target short-term incentives and target long-term incentives for the senior executive team, the Committee does not believe in a “one size fits all” approach and looks at the circumstances of each executive when determining whether to benchmark using the full comparator group or whether a different approach is warranted. When benchmarking executives who are paid in Canadian dollars against roles that are paid in US dollars, the Company uses the five-year average exchange rate between Canada and the US to smooth out the impact of currency fluctuations.

 

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The following chart shows where Emera was positioned compared to the companies in both the Canadian and the US comparator groups based on selected key financial metrics – market capitalization, total enterprise value, assets, revenues, and earnings before interest, taxes, depreciation and amortization (“EBITDA”).

Emera vs. Pay Benchmarking Comparator Groups

LOGO

 

(1)

As at date of analysis, February 13, 2020.

(2)

As at December 31, 2019.

(3)

Last 12 months as at December 31, 2019.

Note: The above table was prepared by Hugessen Consulting Inc. using data from S&P Capital IQ.

In addition to using publicly disclosed compensation data from the companies in the comparator group, the MRCC also uses Mercer’s Total Compensation Survey for the Energy Sector to benchmark executive compensation using data from energy and services companies with similar revenues to Emera. To provide sufficient data in some cases, the Mercer Benchmark Database Survey, which is a general industry database, is also used to expand the survey scope to include Canadian general industry companies of similar size to Emera.

With the assistance of Hugessen and Mercer, the Committee conducted a compensation benchmarking review of the executive team at the end of 2019 to set 2020 pay using the comparator group and survey data, and undertook a review of the competitiveness and appropriateness of Emera’s compensation programs. More details on the results of the review are provided in the next section.

 

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ANNUAL COMPENSATION REVIEW PROCESS

For each executive position, a range for base salary, target short-term incentive and target long-term incentive is established annually, using the benchmarking data along with other information on industry trends for positions of similar scope and responsibility.

The President and CEO conducts annual performance assessments on members of the senior management team, including each of the NEOs, which shape the annual salary adjustment recommendations. Based on the performance assessments and the benchmarking data, the President and CEO then recommends total target compensation for each senior leader, including the NEOs (but excluding himself) to the MRCC for review and approval. With respect to the President and CEO, the Board conducts an annual performance assessment and the MRCC reviews benchmark data and other information on industry trends for positions of similar scope.

Following this process, the MRCC makes recommendations for total target compensation for the senior management team, including the President and CEO and the other NEOs, to the Board of Directors. As part of the annual compensation review process, the MRCC reviews emerging best practices and risk considerations.

At the end of 2019, both management’s compensation advisor, Mercer, and the Committee’s compensation advisor, Hugessen, provided the results of their benchmarking reviews, which assisted in setting the compensation levels for the NEOs for 2020.

In light of Mr. Balfour’s relative positioning against other CEOs in the Company’s peer group and given his strong performance as President and CEO, Mr. Balfour’s total compensation was increased to $7 million. The entirety of his increase was devoted to his long-term incentive target, which was increased to 500 per cent of his base salary. Mr. Balfour’s base salary and short-term incentive target were not changed. In keeping with the Company’s pay-for-performance approach, the majority of Mr. Balfour’s target compensation consists of incentive compensation, which links payouts to the achievement of key objectives toward the Company’s corporate strategy and performance metrics that measure long-term shareholder value.

Ms. Tower received a $25,000 increase to her base salary and Mr. Blunden and Mr. Marchand both received $10,000 increases to their base salaries, which reflected their relative positioning against market. Mr. Blunden’s long-term incentive target was also increased from 165 per cent to 180 per cent. Mr. Bennett did not receive a change to his target compensation in 2020.

The compensation changes from 2019 to 2020 are summarized below. All changes were effective January 1, 2020:

 

    

Base salary

 

  

 

Short-term incentive

target (% of base salary)

 

  

 

Long-term incentive target (% of base salary)

 

  

 

Total target compensation

(% increase)

 

  

Compensation at risk

 

           

Scott Balfour

   No change    No change   

Increase from

390% to 500%

 

   18.64   

Increase from

83% to 86%

 

           

Greg Blunden

  

Increase from $550,000

to $560,000

   No change   

Increase from

165% to 180%

   6.38   

Increase from

70% to 71%

 

           

Nancy Tower

  

Increase from $600,000

to $625,000

   No change    No change    4.17   

Increase from

68% to 69%

 

           

Robert Bennett

   No change    No change    No change    No change   

No change

(65%)

 

           

Bruce Marchand

  

Increase from $500,000

to $510,000

 

   No change   

Increase from

145% to 160%

   7.02   

Increase from

67% to 69%

 

As a result of the changes, the variable or at-risk component of the NEOs’ compensation averaged 72 per cent in 2020. The changes made to the compensation of the respective NEOs in 2020 are also reflected in the NEO Summary Compensation Table.

 

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ELEMENTS OF COMPENSATION

Base Salary

As noted in Benchmarking Data, the MRCC is responsible for annually reviewing the composition of the compensation the Company pays its executives, including base salary. While the MRCC focuses on total compensation, base salary remains an important part of the overall compensation package the Company offers its executives. See table above for 2020 base salary increases.

Short-term Incentive Program

The compensation awarded under the Short-term Incentive Program links a portion of an executive’s compensation to the achievement of predetermined levels of performance in support of corporate and business unit objectives. These objectives are designed to focus on short-term goals (typically on an annual basis) that are intended to deliver value to customers and contribute to increased shareholder value in the longer term. Emera has adopted the scorecard approach to translate corporate strategies into measurable incentive plan goals. Target payouts under the scorecards are generally set as a percentage of salary and are benchmarked against the median for positions with similar responsibilities in comparator companies.

On the recommendation of the MRCC, the Board of Directors of Emera approves scorecards that set forth corporate objectives and related threshold, target and stretch performance levels to be achieved each year. Short-term incentive payouts for the majority of senior management, including the NEOs, are based on scorecard results with potential payouts ranging from 0 to 200 per cent of target.

Short-term incentive payouts for all NEOs are calculated based on results achieved through a corporate scorecard.

 

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2020 Short-term Incentive Results

2020 Emera Corporate Scorecard

The scorecard for Emera (“Emera Corporate Scorecard”) was developed by management and approved by the Emera Board of Directors, on the recommendation of the MRCC, at the beginning of 2020. It was used to determine the short-term incentive payout for our corporate-level NEOs, Mr. Balfour, Mr. Blunden and Mr. Marchand.

The Emera Corporate Scorecard objectives were based on the Company’s Business Plan for the year and established threshold, target and stretch performance standards for each objective.

The following table shows the elements and results of the Emera Corporate Scorecard for 2020.

 

 

    Emera corporate

    objective

  

 

Weighting  

(%)  

   Threshold ($)      Target ($)      Stretch ($)      Actual result ($)     

 

Percentage       

payout (%)  (1)    

 

Cash from

Operations (2)

   30      1,357.6M      1,697M      2,036.4M      1,634M      27      

 

Net Income

After Tax (2)

   40      570.35M      671M      771.65M      759M      75      

 

Safety

   10     

 

Objectives included:

•  90% of Emera Inc. employees have completed a Personal Safety Plan.

•  Proactive Safety Reporting (PAIR => 450) and 90% of Emera Inc.’s supervisors and managers complete the Emera Safety Leadership training by end of Q4.

•  Develop Emera Safety Performance Index for all Affiliates with direction from Emera/Affiliate safety teams and approval from Emera Leadership Safety Advisory Council.

  

 

Stretch achieved;  

however, upon  

recommendation  

of management,  

reduced to 0  

for most senior  

executives in light  

of contractor  

fatality  

   0      

 

Environment

   10     

 

Objectives included:

•  All areas of major risk, identified through the Environmental Audit, have accompanying risk mitigation programs and the businesses are compliant with them.

•  Emera’s electric utilities develop coal generation exit plans by Q4 + environmental management system critical targets are 100% complete.

•  Emera will articulate its vision and mandate to support a deeply decarbonized future + implementation of a consistent protocol for climate related, high impact, environmental risk preparedness and adaptation.

  

 

Stretch achieved  

   20      

 

People

   10     

 

Objectives included:

•  Introduce new training for hiring managers with a view to eliminating unconscious bias and increasing diversity in recruitment.

•  Implement year 1 of the Emera Learning & Development Strategy.

•  Improve Emera’s overall Culture Index in the 2020 Employee Survey (=> 77%) + at least 90% of Emera Inc. employees and Directors complete one module of the new cybersecurity training by end of Q4.

  

 

Stretch achieved  

   20      
    

 

100  

 

            

 

Total: 142      

 

 

(1)

Percentage payouts, below or above target for financial measures, are interpolated on a scale between each level of performance (50 per cent for threshold, 100 per cent for target and capped at 200 per cent for stretch).

(2)

Cash from operations and net income after tax for compensation purposes do not have a standardized meaning as prescribed by GAAP. Calculation of these measures for 2019 is discussed in the footnotes in the following table.

 

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The financial targets reflected in the Scorecard are established in linkage to per share outcomes but are set at absolute levels to avoid the risk of incentive impacts influencing the timing of financing decisions within the year. Cash from operations fell slightly below target but well above threshold and net income after tax results fell between the target and stretch levels of performance.

In 2020, we saw significant progress and success in the achievement of our Safety Scorecard metrics, with all Threshold, Target and Stretch objectives fully achieved, and with best ever performance across a number of metrics including injury rate, lost time injury rate and proactive incident reporting rates. Across Emera we saw a sustained and focused effort on the safe execution of high-risk work activities and reporting. Regrettably, in October, Nova Scotia Power experienced a workplace fatality of a contract worker at the Marshall Falls reservoir in Sheet Harbour. As a result, on the recommendation of management with the support of the HSE Committee of the Board, the safety measure was reduced from 20 per cent to 0 per cent for the NEOs.

The cash from operations and net income after tax figures that are shown in the Emera Corporate Scorecard are adjusted from the Company’s reported figures. The Company considers the following general principles when determining whether it should adjust financial results for incentive plan purposes:

 

   

The Company adjusts the reported figures for specific items the Company believes are significant, but not reflective of underlying operations in the period.

   

Incentive compensation should be directly linked to the performance of the core business and delivering on the plan of record. Meaningful accounting gains or losses are generally the result of strategically or financially driven transactions in which there has been direct involvement and support of the Board; therefore, the impacts of the transactions should typically be excluded from incentive compensation, except as noted below. The Company does not want its strategically or financially driven decisions to be influenced by compensation impacts.

   

The Company should, however, consider including all or some portion of the gain (positive impact) or loss (negative impact) if such gain or loss appropriately reflects the value creation or value destruction and overall performance of management in the decision or execution of the transaction leading to such gain or loss.

   

Perfect alignment of performance and compensation can be elusive from year to year. Therefore, the Board reserves the right to adjust incentive payouts in either direction to satisfy itself that there is close alignment between performance and compensation.

 

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The table below shows the reconciliation between the reported and adjusted figures used in the Emera Corporate Scorecard:

 

Cash from operations reconciliation (in millions $)

     2020  

 

Reported cash flow before working capital

     1,420  

Add: Change in working capital

     217  

Operating cash

     1,637  

Deduct: Adjustment to translate USD earnings to budgeted foreign exchange rate

     (22

Add: Adjustment for transaction costs related to the sale of Emera Maine, pre-tax

     19  

Adjusted cash from operations for compensation purposes

     1,634  

Net income after tax reconciliation (in millions $)

     2020  

 

Reported net income after tax

     938  

Deduct: Gain on sale of Emera Maine, net of tax and transaction costs

     (309

Add: Incremental Emera Maine gain, net of tax

     100  

Add: Impairment charges, net of tax

     26  

Add: After-tax mark-to-market loss

     10  

Deduct: Adjustment to translate USD earnings to budgeted foreign exchange rate

     (6

Adjusted net income after tax for compensation purposes

     759  

The table below shows how Emera’s cash from operations and net income after tax for compensation purposes has trended from 2016 to 2020 (the amounts shown are as at December 31 of each year).

 

       2016 (3)        2017 (4)        2018 (5)        2019 (6)(7)        2020     

 

Cash from Operations ($) (1)

  

 

 

 

878M    

 

 

  

 

 

 

1,218M    

 

 

  

 

 

 

1,619M    

 

 

  

 

 

 

1,502M        

 

 

  

 

 

 

1,634M  

 

 

Net Income After Tax ($) (1)(2)

     302M            535M            640M            617M                759M    

 

(1)

Cash from operations and net income after tax for compensation purposes are non-GAAP measures and do not have standardized meanings as prescribed by USGAAP.

(2)

Net income after tax for compensation purposes reflects reported net income, adjusted for the items discussed in footnotes 2, 3, 4 and 5 in the Earnings Per Share table in Performance Share Unit Plan. In addition, net income after tax for compensation purposes was further adjusted in 2016 to exclude income related to the sale of Algonquin Power & Utilities Corp., and a gain realized on the reduction of the contingency funding in the Barbados Self Insurance Fund.

(3)

Cash from operations for compensation purposes in 2016 reflected net cash provided by operating activities adjusted for the cash flow effect of acquisition costs including legal, advisory and financing costs related to the pending TECO Energy, Inc. acquisition.

(4)

Cash from operations for compensation purposes in 2017 reflected net cash provided by operating activities adjusted to translate USD-generated cash flow to the budgeted foreign exchange rate of $1.00 USD = $1.33 CAD. Net income after tax has been adjusted for mark-to-market adjustments, the estimated impact of the provisional revaluation of US non-regulated net deferred income tax assets as a result of US tax reform and to translate USD earnings to the budgeted foreign exchange rate of $1.00 USD = $1.33 CAD. The Company translates net cash provided by operating activities and USD earnings to CAD earnings using a budgeted foreign exchange rate to ensure that fluctuations in the foreign exchange rate do not positively or negatively impact the measurement of the Company’s performance results against its targets.

(5)

Cash from operations for compensation purposes in 2018 reflected net cash provided by operating activities adjusted to translate USD-generated cash flow to the budgeted foreign exchange rate of $1.00 USD = $1.23 CAD. Net income after tax has been adjusted for mark-to-market adjustments and to translate USD earnings to the budgeted foreign exchange rate of $1.00 USD = $1.23 CAD. The Company translates net cash provided by operating activities and USD earnings to CAD earnings using a budgeted foreign exchange rate to ensure that fluctuations in the foreign exchange rate do not positively or negatively impact the measurement of the Company’s performance results against its targets.

(6)

Cash from operations for compensation purposes in 2019 reflected net cash provided by operating activities adjusted for transaction costs related to the sale of Emera Maine and to translate USD-generated cash flow to the budgeted foreign exchange rate of $1.00 USD = $1.30 CAD. Net income after tax has been adjusted for mark-to-market adjustments, the Grand Bahama Power Company impairment charge (as described in the “Non-GAAP Financial Measures” section of Management’s Discussion and Analysis for 2019), transaction costs related to the sale of Emera Maine, and to translate USD earnings to the budgeted foreign exchange rate of $1.00 USD = $1.30 CAD. The Company translates net cash provided by operating activities and USD earnings to CAD earnings using a budgeted foreign exchange rate to ensure that fluctuations in the foreign exchange rate do not positively or negatively impact the measurement of the Company’s performance results against its targets.

(7)

The decline in cash from operations and net income after tax from 2018 to 2019 was expected, primarily as a result of the strategic decision to sell assets in 2019.

Cash from operations and net income after tax have generally trended upwards over the last five years. Emera’s scorecard payouts on average over the same period have been 24 per cent over target.

 

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2020 Tampa Electric Corporate Scorecard

The scorecard for Tampa Electric Company (“Tampa Electric Corporate Scorecard”) was developed by management and approved by the Tampa Electric Company Board of Directors. It was used to determine the short-term incentive payout for Ms. Tower.

 

 

Tampa Electric

corporate objective

 

  

 

Weighting  

(%)  

  

 

Threshold ($)  

   Target ($)      Stretch ($)      Actual result ($)     

 

Percentage       

payout (%)  (2)    

 

Net Income (1)

  

 

35  

  

 

326.5M  

  

 

343M  

  

 

359.5M  

  

 

371.9M  

  

 

70      

 

Cash Flow (1)

  

 

5  

  

 

618.5M  

  

 

687.3M  

  

 

756M  

  

 

684.2M  

  

 

4.9      

 

Safety

   20     

 

Objectives included:

•  All employees must be represented by a Safety Committee by year end. A schedule for regular Safety Meetings must be developed by year end. Performance Coaches will develop Personal Safety Plans (“PSP”) by end of Q2.

•  PAIR ³ 1000, Safety Leadership training conducted with 90% of Performance Coaches by year end, and complete > 90% of Executive Safety Leadership Engagement Plan.

•  Root Cause Analysis (“RCA”) training completed for the identified target group by end of Q4, and Safety Performance Index developed that is approved by the Emera Leadership Safety Advisory Council (“ELSAC”).

  

 

Stretch  

achieved  

   40      

 

People

   10     

 

Objectives included:

•  At least 50 employees involved in committee work aimed at identifying/assessing opportunities to improve cost structure and/or streamline processes.

•  Implement the Inclusion and Diversity Plan – specifically, create an I&D Council in Q1, launch/communicate the I&D initiative to all employees in Q3, and create an education and training plan by Q4.

  

 

Target  

achieved  

   10      

 

Customer

   15     

 

Objectives included:

•  Complete TEC customer segmentation research to shape future service offerings, and 2020 Customer Communication Plan and 2020 Stakeholder Engagement Plan developed and implemented in support of next Rate Application.

•  Achieve ³ 70% of the Key Service Levels and Participation Index, and 90% completion of the deliverables as listed in the Rate Application Action Plan.

•  Successfully achieve ³ 70% of Power, Quality and Reliability Index, MAIFIe < 8.9, and TEC develops a public

commitment to CO2 emission reduction.

  

 

Stretch  

achieved  

   30      

 

Asset

Management

   15     

 

Objectives included:

•  Big Bend Modernization project achieves 2020 construction milestones, and develop the data analytics plan for AMI.

•  Complete Tranche 4 project (“Durrance”), achieve all Solar Wave 2 project milestones, and implement improved capital management process (including Capital Camp) company wide.

•  Develop plan to advance TEC’s digital capabilities through collaboration with business leaders (and in alignment with Emera’s Digitalization initiatives).

  

 

Stretch  

achieved  

   30      
    

100  

 

            

Total: 184.9      

 

 

(1)

The financial figures for Tampa Electric are shown in USD. Cash from operations and net income after tax for compensation purposes do not have a standardized meaning as prescribed by GAAP.

(2)

Percentage payouts, below or above target for financial measures, are interpolated on a scale between each level of performance (50 per cent for threshold, 100 per cent for target and capped at 200 per cent for stretch).

 

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2020 Emera Technologies Scorecard

The scorecard for Emera Technologies LLC (“Emera Technologies Corporate Scorecard”) was developed by management and approved by the Emera Technologies LLC (“ETL”) Board of Directors. It was used to determine the short-term incentive payout for Mr. Bennett. The Emera Technologies Corporate Scorecard contained measures relating to the development, testing and commercialization of new technologies and the establishment of strategic partnerships related to these measures. The scorecard result was 100 per cent of target. During 2020, ETL made significant progress advancing its business objectives. An updated 2020 Business Strategy was presented to the ETL Board of Directors in June 2020. Customer feedback from both Kirkland Airforce Base in Albuquerque, New Mexico and Lennar Homes resulted in positive feedback in the categories of planning and installation, product operation and customer support. Details on the Emera Technologies Corporate Scorecard have not been included due to its commercial sensitivity.

Long-term Incentive Program

With the introduction of the Restricted Share Unit Plan in 2020, there were three primary components of long-term incentive compensation for senior management, including the NEOs: the Performance Share Unit Plan (the “PSU Plan”), the Restricted Share Unit Plan (“RSUs”), and the Senior Management Stock Option Plan (the “Stock Option Plan”). The MRCC is responsible for granting PSUs, RSUs, and stock options.

The number of PSUs, RSUs, and stock options granted to senior management is determined after considering competitive benchmarking data and the individual’s level of responsibility within the Company. Grants are calculated each year based on each executive’s long-term incentive target percentage and base salary and, generally, the grant amount increases with the level of responsibility. The values of PSUs, RSUs and stock options increase or decrease over the term of a particular grant based on increases or decreases in Emera’s common share price.

The MRCC considers previous grants and looks at a history of total compensation each year before approving any new PSU, RSU or stock option grants for senior management (including the NEOs). This helps to ensure grants remain reasonable in light of market data, the performance of the Company and the performance of the individual.

In 2020, PSUs made up 50 per cent of the target long-term incentive compensatory value for Emera’s most senior executive officers, with the remaining 50 per cent divided equally between RSUs and stock options. This is a change from 2019 where 75 per cent of target was allocated to PSUs and the remaining 25 per cent allocated to options. This new structure for 2020 aligns closely with market practice while still maintaining our company’s pay-for-performance philosophy. The RSU plan also acts as a retention feature as there is less risk of payout volatility with these awards.

More details about the PSU Plan, the RSU Plan, and the Stock Option Plan are set forth below.

Performance Share Unit Plan

The PSU Plan is designed to retain and incentivize employee participants by allowing senior management and key employees in specific roles to participate in the long-term success of the Company. A PSU is a notional share unit that is based on the value of an Emera common share – the value of a PSU changes directly in correlation to the value of an Emera share. PSUs also earn dividends similar to Emera shares; when a dividend is paid on Emera’s common shares, each participant is allocated additional PSUs based on the dividend paid on an equivalent number of Emera common shares.

Each year, designated senior leaders are awarded PSUs based on a pre-determined target of their base salary and the average 50 trading-day Emera common share price immediately preceding the effective grant date (the average is used to smooth out any short-term fluctuations in the share price). Each PSU grant has a three-year performance period. In addition to being affected by fluctuations in the Emera share price, the value of a PSU is also dependent on the achievement of financial objectives that help measure the increase in shareholder value. The MRCC establishes these financial objectives at the beginning of the performance period. By linking the value of the PSUs to Emera’s financial performance over the three-year vesting period, the plan aligns the interests of senior leaders with the interests of Emera’s shareholders and helps ensure that payouts are consistent with Company performance and shareholder experience. All PSU grants and payouts must be approved by the MRCC.

At the end of the performance period, a performance factor is applied to the PSU grant based on the achievement of the financial objectives. If the Company fails to meet the performance objectives for a particular PSU grant, the Plan may pay out at less than target, or may not pay out any amounts at all. Even if targets are exceeded, the maximum performance factor is 200 per cent.

 

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Accordingly, the amount payable to participants, including NEOs, at the end of the three-year performance period is determined by:

 

  PSU Payout    =    Original Grant + Notional Dividends    x    Performance Factor    x    Closing Share Price

Similar to the methodology on the grant, the payout is based on the average 50-trading day closing price for Emera common shares at the end of the three-year performance period to smooth out short-term price fluctuations.

PERFORMANCE SHARE UNIT PLAN RESULTS

The 2018 PSU grant had a performance period of January 1, 2018 to December 31, 2020 and was subject to two equally weighted performance metrics:

 

1.

EPS growth, which is a fundamental measure of the increase in profitability of the Company;

2.

Growth in cash from operations, which measures the Company’s success in focusing on cash generation and is a key driver of long-term value for shareholders.

In addition to the above metrics, the 2018 PSU grant was subject to a TSR modifier, which could increase or decrease the performance factor resulting from the two performance metrics by 25 per cent based on Emera’s TSR compared to the TSR of the S&P/TSX Capped Utilities Index over the three-year performance period. If Emera’s TSR was positioned in the top quartile of performance of companies in the S&P/TSX Capped Utilities Index, the performance factor would be increased by 25 per cent; if Emera’s TSR was positioned in the bottom quartile, the performance factor would be reduced by 25 per cent. There is no adjustment if Emera’s TSR is in the second or third quartile of performance. This allowed the Company to focus on its specific business objectives, but still manage shareholder expectations by adjusting the results for relative performance.

The performance factor could range from 0 per cent to 200 per cent. The maximum performance factor is 200 per cent, even with the impact of the TSR modifier. If the performance metric results multiplied by the TSR modifier exceed 200 per cent, the performance factor would be capped at 200 per cent. In addition, if Emera’s TSR is negative on an absolute basis, then the payout multiplier cannot be above 1.0 (100 per cent), regardless of whether the Company is in the top quartile of performance. This scenario could arise in situations where general market performance of the companies in the S&P/TSX Capped Utilities Index is negative and Emera’s TSR is higher while still being negative. This provision helps ensure payouts are reasonable when shareholders experience low returns on their investment.

In addition, dividends had to be maintained at or higher than the December 31, 2018 levels; if dividends were reduced, the second performance factor would be deemed to be zero regardless of EPS growth.

The threshold, target and stretch levels and results are shown in the table below:

 

2018 PSU grant metric

     Weighting        Threshold (50%)        Target (100%)        Stretch (200%)  

EPS: three-year compound annual growth rate

     50%        4%        8%        12%  

Operating cash flow after working capital: three-year

compound annual growth rate

     50%        4%        10%        16%  

 

The results were as follows:

 

           

2018 PSU grant metric

     2017        2020       

Three-year
compound annual
growth rate
 
 
 
    


Weighted
performance
result (out of
50%)
 
 
 
 

EPS for incentive compensation purposes

     $2.46        $3.08        7.8%        49%  

Operating cash flow after working capital

     $1,193M        $1,657M        11.6%        63%  
                         Performance Factor = 112%  

 

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The EPS and cash from operations figures that are shown in the table above are adjusted from the Company’s reported figures. Similar to the approach used for determining the corporate scorecard results, the Company adjusts the reported figures for specific items the Company believes are significant, but not reflective of underlying operations in the period. The operating cash flow reconciliation is shown in the 2020 Emera Corporate Scorecard. The table below shows the reconciliation between the 2017 and 2020 reported adjusted EPS figures and the EPS figures used for incentive plan purposes.

 

2017 EPS reconciliation ($)

     2017  

Adjusted EPS (basic)

     2.46  

No changes made to Adjusted EPS (basic)

      

EPS for compensation purposes

     2.46  

 

2020 EPS reconciliation ($)

     2020  

Adjusted EPS (basic)

     2.68  

Add: Incremental Emera Maine gain, net of tax

     0.40  

EPS for compensation purposes

     3.08  

The Committee applied the principles laid out in 2020 Emera Corporate Scorecard in determining the adjustments to the reported figures.

The resulting overall performance factor applied to the 2018 PSU grant was 112 per cent (or 1.12), based on Emera’s EPS growth rate falling between threshold and target and the growth in operating cash flow exceeding target. Since Emera’s TSR was between median and the 75th percentile of performance of the companies in the S&P/TSX Capped Utilities Index for 2018 to 2020, the relative TSR modifier was not triggered.

The total payout for all PSU Plan participants in respect of the 2018 PSU grant was approximately $28.7 million. The payout for each participant was 147 per cent of the original grant value (other than participants whose payouts were prorated due to retirement or leave of absence), which factors in share price appreciation, notional dividend reinvestment and the performance factor.

 

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The table below shows how Emera’s EPS for compensation purposes has trended from 2016 to 2020 (the amounts shown are as at December 31 of each year).

 

     2016 (2)      2017 (3)      2018 (4)      2019 (5)      2020 (6)  

Earnings per share ($) (1)

     2.77            2.46            2.88            2.54            3.08      

 

(1)

EPS for compensation purposes is a non-GAAP measure and does not have a standardized meaning as prescribed by USGAAP. The Company measures EPS for compensation purposes by adjusting reported EPS for specific items the Company believes are significant, but not reflective of underlying operations in the period, as detailed in the footnotes below.

(2)

EPS for compensation purposes in 2016 reflected reported EPS adjusted for the income effect of Emera’s held-for-trading derivative instruments and the mark-to-market adjustments included in Emera’s equity income related to the business activities of BSPC, the amortization of transportation capacity recognized as a result of certain trading and market transactions, the mark-to-market adjustment related to an interest rate swap in Brunswick Pipeline as well as the mark-to-market adjustments included in Emera’s other income related to the effect of USD denominated currency and forward contracts put in place to economically hedge the anticipated proceeds from Emera’s Debenture Offering. 2016 EPS was further adjusted for purposes of calculating the 2017 PSU grant performance results as referenced in the 2016 EPS Reconciliation table.

(3)

EPS for compensation purposes in 2017 reflected reported EPS adjusted for the income effect of Emera’s held-for-trading derivative instruments and the mark-to-market adjustments included in Emera’s equity income related to the business activities of BSPC, the amortization of transportation capacity recognized as a result of certain trading and market transactions, the mark-to-market adjustment related to an interest rate swap in Brunswick Pipeline as well as the estimated impact of the provisional revaluation of US non-regulated net deferred income tax assets as a result of US tax reform.

(4)

EPS for compensation purposes in 2018 reflected reported EPS adjusted for the income effect of Emera’s held-for-trading derivative instruments and the mark-to-market adjustments included in Emera’s equity income related to the business activities of BSPC, the amortization of transportation capacity recognized as a result of certain trading and market transactions, the mark-to-market adjustment related to an interest rate swap in Brunswick Pipeline and the mark-to-market adjustment related to equity securities held in BLPC and Emera Reinsurance.

(5)

EPS for compensation purposes in 2019 reflected reported EPS adjusted for the income effect of Emera’s held-for-trading derivative instruments and the mark-to-market adjustments included in Emera’s equity income related to the business activities of BSPC, the amortization of transportation capacity recognized as a result of certain trading and market transactions, the mark-to-market adjustment related to an interest rate swap in Brunswick Pipeline, the mark-to-market adjustment related to equity securities held in BLPC and Emera Reinsurance, the GBPC impairment charge recognized in 2019 (as described in the “Non-GAAP financial measures” section of Management’s Discussion and Analysis) and the adjustments referenced in the 2019 EPS Reconciliation table.

(6)

EPS for compensation purposes in 2020 reflected reported EPS adjusted for the income effect of Emera’s held-for-trading derivative instruments and the mark-to-market adjustments included in Emera’s equity income related to the business activities of BSPC, the amortization of transportation capacity recognized as a result of certain trading and market transactions, the mark-to-market adjustment related to equity securities held in BLPC and Emera Reinsurance, the mark-to-market adjustment related to Emera’s foreign exchange cash flow hedges entered to manage foreign exchange earnings exposure, certain non-cash impairment charges recognized in 2020, and the adjustment referenced in the 2020 EPS Reconciliation table.

2020 PSU Grant Performance Metrics

The Company’s long-term focus continues to be on EPS growth and cash generation as the fundamental drivers of long-term shareholder value creation. Accordingly, the Company used the following two weighted metrics for the 2020 PSU grant:

 

1.

EPS growth, which continues to be a fundamental measure of the increase in profitability of the Company;

2.

Growth in cash from operations before working capital, which measures the Company’s success in focusing on cash generation and is a key driver of long-term value for shareholders.

These two metrics are the same metrics that were used for the 2019 PSU grants, however, the weighting for the 2020 PSU grants has changed. In 2019, the metrics were weighted equally but for the 2020 grants, the EPS growth is weighted at 75 per cent and the growth in cash from operations is weighted at 25 per cent. This is due to the increased focus on EPS relative to cash flow.

The combination of the two metrics effectively measure management’s contributions to the creation of long-term value for shareholders.

In addition to the above metrics, the Company continues to use the relative TSR modifier for the 2020 PSU grant, which is described in Performance Share Unit Plan Results.

 

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The performance period for PSUs granted in 2020 is from January 1, 2020 to December 31, 2022 and the table below shows the performance factor levels:

 

Metric   Weighting     Threshold (50%)     Target (100%)     Stretch (200%)    

Average annual growth in EPS, removing mark-to-market gains/ losses

    75%       2%       6%       10%    

Average annual growth in cash from operations (before working capital)

    25%       2%       6%       10%    
Modifier        

<25th percentile

(bottom quartile)

   

75th–25th

percentile

   

>75th percentile  

(top quartile)  

 

Emera’s TSR vs. S&P/TSX Capped Utilities Index
TSR; multiply metric results by stated multiplier

            0.75       1.0       1.25    

The threshold, target and stretch levels of performance are consistent with those for previous grants, and are calibrated against a combination of the Company’s five-year business plan projections, dividend growth rate, actual and forecasted performance levels of peers, and overall assessment of the expectations of shareholders.

The performance targets for the PSU awards are used for compensation purposes only and are not suitable for any other purpose. There is no assurance that any performance level will be met. The targets may also constitute forward-looking information. Forward-looking statements are based upon a number of assumptions and are subject to a number of known and unknown risks and uncertainties, any of which are beyond Emera’s control, which could cause actual results to differ materially from the performance targets. Please see the cautionary statement in Emera’s 2020 Annual Report respecting risks and assumptions relevant to Emera’s determination of performance targets for compensation purposes.

Restricted Share Unit Plan

The Restricted Share Unit Plan was introduced in 2020 after a market review determined that Emera had a higher weighting of PSUs than most of its peers. The plan is designed to achieve more balance between risk and leverage in Emera’s long-term incentive programs, while remaining consistent with our pay-for-performance philosophy.

A RSU is a notional share unit that is based on the value of an Emera common share – the value of a RSU changes directly in correlation to the value of an Emera share. RSUs also earn dividends similar to Emera shares; when a dividend is paid on Emera’s common shares, each participant is allocated additional RSUs based on the dividend paid on an equivalent number of Emera common shares.

Similar to PSUs, designated senior leaders are awarded RSUs annually based on a pre-determined target of their base salary and the average 50 trading-day Emera common share price immediately preceding the effective grant date (the average is used to smooth out any short-term fluctuations in the share price). Each RSU grant has a three-year performance period.

At the end of the performance period, RSUs are valued and paid out by multiplying the original number of RSUs granted and all additional notional dividends by the average 50-trading day closing price for Emera common shares at the end of the three-year performance period. The calculation is as follows:

 

  RSU Payout    =   Original Grant + Notional Dividends    x    Closing Share Price   

 

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Senior Management Stock Option Plan

The Board of Directors has delegated the administration of the Stock Option Plan to the MRCC. The MRCC is responsible for approving, based on management’s recommendation, which employees of the Company and its affiliates will be eligible to participate in the Stock Option Plan.

Stock options are designed to deliver a percentage of the long-term incentive opportunity for senior management, including the NEOs, and are an important component of competitive executive compensation. Grants are calculated each year based on each executive’s long-term incentive target percentage and base salary and, generally, the grant amount increases with the level of responsibility. The Company considers stock options to be in alignment with long-term shareholder interests and the MRCC continues to review the use of options annually. All NEOs participate in the Stock Option Plan and have received stock options in 2020 as part of their long-term incentive.

The Company has historically valued stock options based on the Black-Scholes valuation methodology. However, the Committee adopted a floor value ratio of 10 per cent in 2015, following a review of market practices on valuation methodologies. If the Black- Scholes methodology leads to a value ratio that is less than 10 per cent, the floor of 10 per cent will apply. All other factors being equal, the use of a higher value ratio leads to fewer options. The exercise price for stock options is the closing price of an Emera common share on the day immediately preceding the effective grant date. Options have a 10-year term and must be exercised before the expiry date and any unexercised options are forfeited upon expiry.

For the 2020 stock option grant, the Black-Scholes valuation resulted in a value ratio ranging from 3.2 per cent to 5.9 per cent. The range was dependent on the number of months over which the volatility calculation was measured, from 12 to 120 months. Because the valuation was below 10 per cent, the Committee applied the floor value ratio, which led to fewer options being granted than if the floor had not been applied. Accordingly, the value of each option granted in 2020 was $6.00, which was 10 per cent of the closing Emera common share price of $60.03 on February 19, 2020, the day immediately preceding the grant date. The share price of $60.03 is also the exercise price for the 2020 grant. The Committee considers the application of a 10 per cent floor to be a prudent step to maintaining stock options as a part of the Long-term Incentive Plan, while reflecting prevailing market conditions.

Stock options vest in 25 per cent increments on the first, second, third and fourth anniversaries of the grant date. Unless a stock option has expired, vested options may be exercised within the 27 months following the option holder’s date of retirement, within six months following the date of termination without cause or the option holder’s death, and within 60 days following the date of termination for cause or resignation. If stock options are not exercised within such time, they expire. However, certain senior executives are entitled to an enhanced retirement vesting provision, which allows unvested stock options to continue to vest and be exercised for two years post-retirement. If a change of control occurs and an executive is terminated for “good reason” as defined in the plan text and in this Circular under Termination and Change of Control Benefits, unvested options held at the time of termination vest immediately and must be exercised by the earlier of either six months from the termination date or the expiry date of the option. Please see Termination and Change of Control Benefits for the NEOs’ entitlements on departure.

The maximum percentage of shares under all security-based compensation arrangements (including the Stock Option Plan and the Employee Common Share Purchase Plan) issuable to insiders of the Company at any time is 10 per cent of the issued and outstanding shares of the Company. The maximum number of shares to be optioned to any one person under the Stock Option Plan is five per cent of the issued and outstanding shares of the Company at the date of the grant of the option. The number of shares issued to insiders, within any one-year period, under all security-based compensation arrangements, will not exceed 10 per cent of the issued and outstanding shares of the Company.

Under the Stock Option Plan, options may be granted in respect of authorized and unissued common shares of the Company to a maximum of 11.7 million shares, or approximately 4.65 per cent of the total issued and outstanding common shares of the Company as of December 31, 2020.

 

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There have been 8,170,108 common shares issued under the Stock Option Plan since its inception, which represents approximately 3.25 per cent of the total issued and outstanding common shares of the Company as of December 31, 2020, leaving 3,529,892 common shares reserved for issuance under the Plan, representing 1.40 per cent of the total issued and outstanding common shares as at December 31, 2020. As outlined previously in the Senior Management Stock Option Plan Amendment section of this Circular, we are proposing an increase of 3,000,000 shares to the Senior Management Stock Option Plan reserve, pending shareholder approval. There are 2,267,782 common shares issuable under actual grants of options, which represent approximately 0.90 per cent of the total issued and outstanding common shares of the Company as of December 31, 2020 and, of that amount, 973,932 are vested and 1,293,850 are unvested.

The Board of Directors of the Company may amend or discontinue the Stock Option Plan by resolution at any time and may, without shareholder approval, make amendments such as changes to vesting provisions and other minor changes of a housekeeping nature; however, shareholder approval is required for any amendment that:

 

   

increases the number of common shares reserved for issuance, except an increase made in proportion to an increase in the number of common shares outstanding due to a stock dividend, stock split, amalgamation, reorganization, merger or similar event;

 

   

extends eligibility to participate to non-employee Directors;

 

   

permits rights under the Stock Option Plan to be transferred other than for normal estate settlement purposes;

 

   

permits awards to be granted under the Stock Option Plan in addition to options;

 

   

increases either of the 10 per cent insider participation limits;

 

   

reduces the option price of an option except for the purpose of maintaining option value in connection with a change of control or pursuant to the provisions in the Stock Option Plan, which permit equitable adjustments to be made to the option price in connection with a stock dividend, stock split, share reclassification, amalgamation, reorganization, merger or similar event;

 

   

extends the term of a stock option beyond the original expiry date;

 

   

permits the expiry of a stock option to be beyond 10 years from its date of grant; or

 

   

deletes or reduces the range of amendments which require shareholder approval under this paragraph.

The table below summarizes certain ratios regarding the Stock Option Plan, namely dilution, burn rate and overhang as defined in the table and measured as a percentage of the weighted average number of shares outstanding for the respective year.

 

     2020 (%)     2019 (%)      2018 (%)  
       

Dilution

       

(number of options outstanding, divided by the weighted average total issued and
outstanding common shares for the applicable fiscal year)

     0.92       0.94        1.81  

Burn rate

       

(number of options granted in an applicable fiscal year, divided by the weighted average
total issued and outstanding common shares for the applicable fiscal year)

     0.20       0.27        0.27  

Overhang

       

(shares available for issuance, plus options outstanding, divided by the weighted average
total issued and outstanding common shares for the applicable fiscal year)

     1.42       1.65        2.80  

The stock options issued under the Stock Option Plan are non-assignable, though the Plan permits transfers from the estate of a deceased option holder to the ultimate beneficiaries. The option can then be exercised by such beneficiaries.

The Company does not provide financial assistance to participants to facilitate the purchase of shares through the Stock Option Plan.

 

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Performance Graph

The following performance graph compares Emera’s cumulative total shareholder return or “TSR” (assuming an investment of $100 and reinvestment of dividends) for its common shares with that of the S&P/TSX Capped Utilities Index and the S&P/TSX Composite Index.

Cumulative Total Return on $100 Investment – December 31, 2015 to December 31, 2020

 

LOGO

 

As at December 31    2015/12 ($)      2016/12 ($)      2017/12 ($)      2018/12 ($)      2019/12 ($)      2020/12 ($)  

LOGO  Emera Inc.

     100.00                 109.57                 118.67                 116.55                 155.78                 157.88   

LOGO S&P/TSX Capped Utilities Total Return

     100.00         117.60         130.09         120.09         165.11         190.34   

LOGO  S&P/TSX Composite Total Return

     100.00         121.08         132.09         120.36         147.89         156.17   

LOGO TDC ($ thousands)

     9,449         11,157         12,869         13,136         13,540         15,608   

Emera’s cumulative TSR for the five-year period from December 31, 2015 to December 31, 2020 was 58 per cent, compared to the 90 per cent return of the S&P/TSX Capped Utilities Index and 56 per cent return of the S&P/TSX Composite Index. Emera’s TSR increased 1 per cent from 2019 to 2020. The above graph also shows total direct compensation for our NEOs over the past six years.

TOTAL SHAREHOLDER RETURN VS. NAMED EXECUTIVE OFFICER COMPENSATION

As noted in A Letter from the Management Resources and Compensation Committee to Our Shareholders, a fundamental principle of Emera’s compensation philosophy is to align pay with performance, by linking a significant portion of the compensation the Company pays its executives to the achievement of objectives measuring whether shareholders are experiencing strong value for their investment.

In light of this principle, at the end of 2020 the Company undertook its annual analysis of the alignment between the President and CEO’s compensation and the experience of shareholders. The analysis reviewed the compensation of the President and CEO over the past 10 years and compared the results to the shareholder experience, as measured by TSR, over the same periods. The review included both realized pay (which consists of amounts paid out for a particular performance year) and realizable pay (which consists of the value of any outstanding equity-based awards).

 

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The analysis looked at the shareholders’ experience using 10 different measurement periods, recognizing that shareholders have acquired their shares at different times. Each period had the same end point (December 31, 2020) but started at a different beginning period, from January 1, 2011 to January 1, 2020. The analysis measured the dollar return per $100 of investment over each period as compared to the President and CEO’s economic experience, measured by the dollars realized and realizable per $100 of target compensation awarded over the same periods.

The following lookback table shows the results of the review:

 

  Pay year       

Target total
direct
compensation 
 
 
(1)(2) 
   

Total realized/
realizable value at
Dec. 31, 2020
 
 
 (3) 
  Measurement period     


Realized/
realizable value of

$100 target pay
awarded to CEO 

 
 

 
(3) 

    


Value of $100
shareholder
investment as of
Dec. 31, 2020 (4)
 
 
 
 
     Difference  
  2011        2,470,109         2,907,824     Jan. 1, 2011 – Dec. 31, 2020      118        267        149  
  2012        2,474,995         4,479,711     Jan. 1, 2012 – Dec. 31, 2020      181        243        62  
  2013        3,573,704         9,461,470     Jan. 1, 2013 – Dec. 31, 2020      265        222        -43  
  2014        3,587,500         9,037,049     Jan. 1, 2014 – Dec. 31, 2020      252        242        -10  
  2015        3,762,500         5,725,379     Jan. 1, 2015 – Dec. 31, 2020      152        184        31  
  2016        4,800,000         4,803,747     Jan. 1, 2016 – Dec. 31, 2020      100        158        58  
  2017        6,000,000         7,187,995     Jan. 1, 2017 – Dec. 31, 2020      120        144        24  
  2018        4,800,000         8,895,058     Jan. 1, 2018 – Dec. 31, 2020      185        133        -52  
  2019        5,900,000         7,804,277     Jan. 1, 2019 – Dec. 31, 2020      132        135        3  
  2020        7,000,000         6,302,270     Jan. 1, 2020 – Dec. 31, 2020      90        101        11  
                         Average      160        183        23  
(1)

The lookback table shows the compensation of the former President and CEO, Chris Huskilson, for 2011 to 2017, and the compensation of the President and CEO, Scott Balfour, for 2018 and 2020.

 

(2)

Includes salary, short-term incentive at target and the grant value of long-term incentives.

 

(3)

Factors in salary, short-term incentive payout, PSU payout, value realized from exercised stock options and the market value of any outstanding PSUs, DSUs and in-the-money unexercised stock options as of December 31, 2020.

 

(4)

Represents the cumulative value of a $100 investment in Emera common shares made on the first day of the period indicated, assuming dividends are reinvested.

The analysis concluded that Emera’s compensation framework provided appropriate alignment between the President and CEO’s compensation and the shareholder experience over the long term. This analysis also assists the Committee in considering various compensation outcomes when considering compensation changes for the President and CEO each year.

In keeping with Emera’s compensation philosophy, a significant component of NEO compensation consists of long-term incentives (PSUs, RSUs and stock options), which are designed to focus executives on the long-term success of the Company. These long- term incentives are directly affected by changes in Emera’s common share price and TSR. This helps create a direct correlation between the shareholder experience and the compensation the Company pays its senior executives.

As described in Performance Share Unit Plan, each PSU grant is subject to the achievement of financial objectives and, at the end of the performance period, a performance factor is applied, which is determined based on the extent to which the Company has met those objectives. The performance factors for the PSU Plan, expressed in terms of a percentage, for the past five years were 150 per cent for each of the performance periods ending in 2015 and 2016, 101 per cent for the period ending in 2017, 65 per cent for the period ending in 2018, 100 per cent for the period ending in 2019 and 112 per cent for the period ending in 2020.

The total annual salary, short-term incentive and PSU payouts in 2020 for the five NEOs totalled $13.5 million, which represents 1.4 per cent of the Company’s net earnings applicable to common shares of $938 million or 2.0 per cent of the Company’s adjusted net earnings applicable to common shares of $665 million, for the period ended December 31, 2020. The MRCC is comfortable that the payout totals for 2020 are reasonable based on the Company’s performance and demonstrate that the Company’s compensation programs are aligned with the interests of our shareholders. Adjusted net earnings is a non-GAAP measure and does not have a standardized meaning as prescribed by USGAAP.

 

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NEO SUMMARY COMPENSATION TABLE

The table below shows the compensation awarded to the Company’s NEOs for the last three fiscal years.

 

Name and principal position      Year        Salary ($)  (1)     

Share-based

awards ($)

 

 (2) 

   
Option-based
awards ($) 
 
(3) 
   

 



Non-equity
incentive plan
compensation

 

Annual
incentive
plans ($) 

 
 
 

 

 
 
(4) 

   

Pension
value

($)

 
 

 

    

All other
compensation

($)

 
 

 (5) 

   

Total  

compensation  

($)  

 

 

 

Scott Balfour

     2020        1,038,461       3,750,209       1,249,800       1,420,000       293,000        36,546       7,788,017    

President and Chief Executive

     2019        1,000,000       2,925,155       974,864       1,142,000       643,000        39,422       6,724,441    

    Officer

     2018        986,673       2,100,156       699,846       1,668,000       634,000        35,993       6,124,668    

Greg Blunden

     2020        581,039       755,995       252,000       556,640       97,000        27,398       2,270,072    

Chief Financial Officer

     2019        547,692       680,587       226,896       439,670       108,000        24,558       2,027,403    
       2018        500,000       562,468       187,530       583,800       273,000        25,318       2,132,116    

Nancy Tower

     2020        647,789       702,905       234,600       808,938       514,000        298,978       3,207,209    

President and Chief Executive

     2019        600,000       674,973       225,040       580,440       416,000        251,000       2,747,453    

    Officer, Tampa Electric

     2018        600,000       674,971       225,036       506,160       337,000        290,142       2,633,309    

    Company

                                                                   

Robert Bennett

     2020        661,721       589,416       196,200       382,328       213,000        169,700       2,212,364    

President and Chief Executive

     2019        630,278       590,637       168,896       567,250       298,000        168,620       2,423,681    

    Officer, Emera Technologies

     2018        615,457       577,156       167,580       608,195       (26,000)        163,271       2,105,659    

    LLC (6)

                                                                   

Bruce Marchand

     2020        529,115       612,017       204,000       434,520       199,000        33,738       2,012,391    

Chief Legal and

     2019        497,692       543,595       181,424       342,600       258,000        24,558       1,847,870    

    Compliance Officer

     2018        448,096       489,295       163,191       450,360       117,000        17,068       1,685,010    

 

(1)

The figure shown represents the actual base earnings paid each year.

 

(2)

The figure shown is the value of PSU and RSU grants as of the effective grant date. The grant value of PSUs and RSUs granted in 2020 was based on the average 50-trading day closing share price up to December 31, 2020 ($54.62). The 50-day share price average is used for PSU and RSU grants to smooth out any short-term fluctuations in share price immediately preceding the grant date. The value of PSUs on payout is subject to the achievement of specific performance objectives over the respective three-year performance period. If those objectives are not met, payouts may be less than the initial value of the grant noted in this column and if performance objectives are exceeded, payouts may be higher than the amount noted in this column.

 

(3)

The value of each stock option granted to the NEOs in 2020 was determined to be equal to 10 per cent of the February 19, 2020 closing share price of $60.03 or $6.00 per option. The Company has adopted a floor value ratio of 10 per cent; if the Black-Scholes methodology leads to a value ratio that is less than 10 per cent, the floor of 10 per cent will apply. The Black-Scholes valuation for 2020 resulted in a value ratio of 3.2 per cent to 5.9 per cent, using an estimated dividend yield of 4.4 per cent, and a risk-free interest rate of 1.91 per cent. The range was dependent on the number of months over which the volatility calculation was measured, from 12 to 120 months, which led to volatility measurements from 10.6 per cent to 14.2 per cent. Because the Black- Scholes valuation was below 10 per cent, the floor of 10 per cent was used to value stock options in 2020, which led to fewer options being granted than if the floor had not been applied.

 

(4)

In 2020, Mr. Balfour, Mr. Blunden and Mr. Marchand participated in the Emera Corporate Scorecard, which had a result of 142 per cent. Ms. Tower participated in the Tampa Electric Corporate Scorecard, which had a result of 184.9 per cent, and Mr. Bennett participated in the Emera Technologies Scorecard, which had a result of 100 per cent. The Short-term Incentive Plan and the 2020 results are described in greater detail in Short-term Incentive Plan. The figures shown reflect amounts earned in the 2020 performance year and paid in 2021. Ms. Tower elected to receive 100 per cent of her short-term incentive payout in the form of DSUs, Mr. Balfour elected to receive 50 per cent of his payout in DSUs, and Mr. Blunden and Mr. Marchand elected to received 25 per cent of their payout in DSUs.

 

(5)

All other compensation in 2020 consists of: for Mr. Balfour, a cash perquisite allowance of $31,000 and other taxable benefits; for Mr. Blunden, a cash perquisite allowance of $21,000 and other taxable benefits; and for Mr. Marchand, a cash perquisite allowance of $20,000 and other taxable benefits. Ms. Tower was required to relocate from Nova Scotia to Tampa, Florida, upon being appointed President and CEO of Tampa Electric; her amount consists of a cash perquisite allowance of $21,000, a housing allowance of $158,000, a cost of living allowance of $93,000, a travel allowance of $21,000, and other taxable benefits. Mr. Bennett is also required to reside in Tampa for his role; his figure consists of a cash perquisite allowance of $20,000 USD, a housing allowance of $72,000 USD, a family travel allowance of $31,746 USD and other taxable benefits. The amount shown in the All Other Compensation column for Mr. Bennett has been converted to CAD using the exchange rate of $1.00 USD = $1.3415 CAD, which is based on the Bank of Canada daily average exchange rate between CAD and USD for 2020. Please see Other Executive Benefits for additional details on the items that are included in these All Other Compensation figures.

 

(6)

Mr. Bennett is paid in USD. His base salary was $475,000 USD, his short-term incentive payout was $285,500 USD, and the PSU portion of his long-term incentive grant was valued in USD. The stock option portion of his long-term incentive grant was valued in CAD and was adjusted to reflect the exchange rate between USD and CAD ($1.00 USD = $1.32 CAD) at the time of grant. Any USD amounts applicable to Mr. Bennett have been converted to CAD in the table using the exchange rate of $1.00 USD = $1.3415 CAD, which is based on the Bank of Canada daily average exchange rate between CAD and USD for 2020. Under the terms of his employment arrangement, USD and CAD are treated on par for purposes of calculating his pensionable earnings under the pension plan.

 

 

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Outstanding Share-based Awards and Option-based Awards

The following table describes all option-based and share-based awards outstanding as of December 31, 2020 for each NEO:

 

     

Option-based awards

(1) (stock options)

    

Share-based awards

(performance share units (PSUs), restricted share units (RSUs)
and deferred share units (DSUs))

 
Name     



Number of
securities
underlying
unexercised
option (#)
 
 
 
 
 
    

Option
exercise
price ($)
 
 
 
    

Option
expiration

date

 
 

 

    

Value of  
unexercised  
in-the-money  

options ($)

 
 
 

 (2) 

    

Number of
shares or unit of
shares that have

not vested (#) 

 
 
 

(3) 

    



Market or payout
value of share-
based awards
that have not
vested ($) (4)
 
 
 
 
 
      


Market or payout
value of vested
share-based awards
that have not been

paid out ($)

 
 
 
 

(5) 

Scott Balfour

     24,990        33.73        4/15/2022        509,046          146,482        8,006,708          4,819,106  
     28,200        34.80        2/12/2023        544,260               
     34,800        32.35        2/11/2024        756,900               
     40,400        42.71        2/11/2025        460,156               
     52,100        46.19        2/17/2026        412,111               
     66,300        45.16        2/14/2027        592,722               
     175,400        39.93        2/13/2028        2,485,418               
     210,100        46.39        2/20/2029        1,619,871               
       208,300        60.03        2/19/2030        –                                 

Greg Blunden

     9,325        45.16        2/14/2027        83,366          31,851        1,740,988          2,385,800  
     23,500        39.93        2/13/2028        332,995               
     36,675        46.39        2/20/2029        282,764               
       42,000        60.03        2/19/2030        –                                 

Nancy Tower

     32,400        42.71        2/11/2025        369,036          30,692        1,677,621          6,428,808  
     32,100        46.19        2/17/2026        253,911               
     44,000        45.16        2/14/2027        393,360               
     56,400        39.93        2/13/2028        799,188               
     48,500        46.39        2/20/2029        373,935               
       39,100        60.03        2/19/2030        –                                 

Robert Bennett(6)

     8,025        46.19        2/17/2026        63,478          19,895        1,458,813          4,230,431  
     18,150        45.16        2/14/2027        162,261               
     31,500        39.93        2/13/2028        446,355               
     36,400        46.39        2/20/2029        280,644               
       32,700        60.03        2/19/2030        –                                 

Bruce Marchand

     9,090        42.71        2/11/2025        103,535          25,597        1,399,122          1,723,319  
     19,500        46.19        2/17/2026        154,245               
     32,500        45.16        2/14/2027        290,550               
     30,675        39.93        2/13/2028        434,665               
     39,100        46.39        2/20/2029        301,461               
       34,000        60.03        2/19/2030        –                                 
(1)

Option-based awards include both vested and unvested options.

 

(2)

The value of all unexercised option-based awards was calculated using a December 31, 2020 closing share price of $54.10.

 

(3)

Unvested share-based awards include PSUs, RSUs and unvested special DSU grants, and any additional PSUs, RSUs and DSUs from dividend reinvestment relating to such grants as of December 31, 2020.

 

(4)

The market or payout value of share-based awards was calculated based on an assumed performance factor of 1.0 and the average closing share price for the last 50 trading days of 2020 ($54.66).

 

(5)

These figures represent only vested DSUs, as PSUs are paid out upon vesting, and are based on the average closing share price for the last 50 trading days of 2020 ($54.66).

 

(6)

For Mr. Bennett, any PSUs that are payable in USD have been converted to CAD in the table using the exchange rate of $1.00 USD = $1.3415 CAD, which is based on the Bank of Canada daily average exchange rate between CAD and USD for 2020.

 

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Incentive Plan Awards – Value Vested or Earned During the Year

The following table describes all option-based awards, share-based awards and non-equity incentives that vested, or were earned, during 2020 for each NEO:

 

Name   

Option-based awards value    

vested during 2020 ($) (1)

  

Share-based awards (performance share      
units (PSUs)  and deferred share units      

(DSUs))      

value vested during 2020 ($) (2)

  

Non-equity incentive plan    

compensation – value earned    

during the year ($) (3)

Scott Balfour

   2,012,456        3,088,026          1,420,000    

Greg Blunden

   597,334        827,041          556,640    

Nancy Tower

   713,332        992,464          808,938    

Robert Bennett

   573,290        833,443          382,328    

Bruce Marchand

   520,161        719,449          434,520    
(1)

Represents the aggregate dollar value that would have been realized if stock options had been exercised on the applicable vesting (eligibility) date in 2020.

(2)

The value of PSUs vested in 2020 is based on the 2018 PSU grant, which had a three-year performance period from January 1, 2018 to December 31, 2020. The payout is calculated based on the original grant with accumulated dividends, multiplied by the performance factor, multiplied by the average closing share price for the last 50 trading days of 2020 ($54.66). The performance factor for the 2018 PSU grant was based on Emera’s growth in EPS and cash flow over the three-year performance and vesting period. The performance factor result was 112 per cent. More details on the PSU Plan and results can be found in Performance Share Unit Plan.

(3)

This amount represents the 2020 incentive payouts as disclosed in the NEO Summary Compensation Table.

Aggregate Option Exercise During 2020 and 2020 Option Values

The following table summarizes the number of common shares, if any, each NEO acquired pursuant to the exercise of stock options in 2020, the aggregate value realized upon exercise, and the number of common shares covered by unexercised options under the Stock Option Plan as at December 31, 2020. The aggregate value realized upon exercise is the difference between the fair market value of the common shares on the exercise date and the exercise price of the option. The value of unexercised in-the-money options at year-end is the difference between the exercise price of the options and the fair market value of the common shares on December 31, 2020, which was $54.10.

 

Unexercised options at

December 31,

2020

    

Value of unexercised in-the-money
options at

December 31, 2020

 
Name    Securities acquired
on exercise (#)
    

Aggregate value

realized ($)

     Exercisable (#)      Unexercisable (#)      Exercisable ($)      Unexercisable ($)  

Scott Balfour

     10        191        370,440        470,150        4,774,692        2,605,793  

Greg Blunden

     37,875        429,544        0        111,500        0        699,125  

Nancy Tower

     0        0        137,825        114,675        1,411,045        778,385  

Robert Bennett

     0        0        36,700        90,075        363,554        589,184  

Bruce Marchand

     10        103        72,965        91,900        695,946        588,510  

Pension Plan Benefits

Emera has adopted a pension oversight framework that sets out the structure and processes for overseeing the management and administration of all pension plans sponsored or administered by Emera and its affiliates to ensure that the liabilities associated with such pension plans are being appropriately managed.

The NEOs are members of the Canadian corporate pension plan (“Pension Plan”), participating on either a defined benefit basis or a defined contribution basis, as well as a supplementary retirement plan (“Supplementary Retirement Plan”), similarly on either a defined benefit or defined contribution basis. For 2020, all NEOs participated in the defined benefit component of the Pension Plan and one NEO also participated in the defined contribution component of the Pension Plan.

 

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Defined Benefit

The following table shows years of credited service, estimated pension amounts and changes to accrued obligations from January 1, 2020 to December 31, 2020 for the NEOs who participated in the Pension Plan on a defined benefit basis.

 

 

           Annual benefits payable                                
Name     

Number of
years credited
service (#)
 
 
 
    
At year-end
($) 
 
(1) 
   
At age 65
($)
 
 
    


Accrued
obligation at the
start of the year
($)
 
 
 
 
    
Compensatory
change ($) 
 
(2) 
   

Non-
compensatory
change ($)
 
 
 (2) 
   

Accrued
obligation at
year-end ($) 
 
 
(3) 

Scott Balfour

     8.7        202,000       403,000        3,102,000        293,000       540,000       3,935,000  

Greg Blunden (4)

     1.3        16,000       16,000        518,000        18,000       37,000       573,000  

Nancy Tower

     23.3        332,000       378,000        6,798,000        514,000       571,000       7,883,000  

Robert Bennett

     32.7        388,000       416,000        8,440,000        213,000       362,000       9,015,000  

Bruce Marchand

     9.0        100,000       116,000        1,636,000        199,000       251,000       2,086,000  

 

(1)

All NEOs were eligible for an immediate pension at year-end. The amount shown is the accrued pension starting at the NEO’s unreduced retirement date if the NEO terminated employment at December 31, 2020.

 

(2)

The compensatory and non-compensatory changes are described in more detail below.

 

(3)

The accrued pension obligation is calculated following the method prescribed under USGAAP (section 715 of the standards of the Financial Accounting Standards Board) and by the Canadian Institute of Chartered Accountants and is based on management’s best estimate of future events that affect the cost of pensions, including assumptions about future salary adjustments and short-term incentive awards.

 

(4)

Mr. Blunden accrues future benefits under the defined contribution component of the Pension Plan and has frozen service under the defined benefit component of the Pension Plan.

The accrued obligation of a pension entitlement is the present value of the expected future annual benefits payable taking into account service accrued to date and the expected salaries used to determine the annual benefit payable at retirement. Each year, the value of the accrued obligation changes as a result of compensatory changes and non-compensatory changes, which are shown in the table above.

Compensatory changes are caused by changes in the annual benefit payable and result primarily from three factors: (i) new accrued service (the employer current service cost); (ii) the impact of salary increases greater than expected on past benefits (estimated increases are already built into the accrued benefit obligation); and (iii) plan changes impacting, for example, accrued service or when benefits are payable (there were no plan changes that materially affected the above figures in 2020).

Non-compensatory changes are caused by interest on the accrued obligation and current service cost, employee required contributions and changes in the assumptions used to calculate the present value of the future annual benefit payment stream. These assumptions include the mortality table, salary scale, retirement assumption and the inflation assumption used for calculating indexing and the discount rate. The non-compensatory changes in 2020 were driven largely by changes in actuarial assumptions as well as interest on the accrued obligation and current service cost. The assumption changes from December 31, 2019 to December 31, 2020 include a change in the discount rate from 3.13 per cent to 2.59 per cent, and a decrease in inflation from 1.75 per cent to 1.50 per cent (which also affects future salary growth expectations). The net effect of the discount rate and inflation changes is to increase obligations.

The defined benefit component of the Pension Plan entitles members to pension benefits based on two per cent of the average of the member’s five highest years of pensionable earnings, multiplied by each year of credited service to a maximum of 35 years credited service. For the NEOs, pensionable earnings include base salary plus up to 50 per cent of their target short-term incentive. Upon a member reaching age 65, pension benefits under the Pension Plan are reduced by an amount approximately equal to the amount payable under the Canada Pension Plan. For members who retire from active service, the pension is payable on an unreduced basis upon the earlier of age 60 or age 55, provided that age and years of service add to at least 85. For members who joined the Pension Plan on or after July 1, 2004, the age 60 unreduced retirement age condition is replaced by age 62 with 15 years of service. A member may also retire on a reduced formula if the member has attained age 55, but does not qualify for an unreduced pension. Spousal benefits are paid on the death of a member at the rate of 60 per cent of regular pension benefits. Pensions are indexed to the consumer price index.

Under the terms of Mr. Balfour’s employment agreement, his average five highest years of pensionable earnings is capped at $1.75 million for purposes of calculating his pension.

 

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For 2020, members of the defined benefit component of the plan contributed 7.4 per cent of eligible earnings up to the year’s maximum pensionable earnings (“YMPE”) under the Canada Pension Plan, and 9.5 per cent of earnings between the YMPE and the amount on which pension benefits may be earned under a registered pension plan as permitted by the Income Tax Act (Canada).

Due to Canada Revenue Agency limitations on the maximum pension benefit that may be paid under the Pension Plan, a portion of the pension the NEOs earned after January 1, 1992 is provided under the terms of the Supplementary Retirement Plan, which is unfunded but secured by a letter of credit deposited in a retirement compensation trust. The Supplementary Retirement Plan is non-contributory. The Supplementary Retirement Plan generally mirrors the terms of the Pension Plan, with the exception that benefits earned on service in the SERP after December 31, 2017 are not indexed on retirement. The Company does not grant additional years of credited service to NEOs under the Pension Plan or Supplementary Retirement Plan.

The defined benefit component of the Pension Plan was closed to new non-union employees hired after January 8, 2013 and to new union employees hired after October 31, 2014. The defined benefit component of the Supplementary Retirement Plan was closed to new entrants as of December 31, 2017. Any employees who become eligible to participate in the Supplementary Retirement Plan after December 31, 2017 will participate in the defined contribution component.

The compensatory and non-compensatory change figures for Mr. Blunden and Ms. Tower include the increase in value of a potential retirement award. Certain employees of the Company hired before August 1, 2007 are eligible for a retirement award if they continue working with the Company until their unreduced retirement date. The retirement award is calculated by multiplying the employee’s weekly base salary immediately preceding retirement by the employee’s number of years of service at retirement, to a maximum of 26 weeks of salary, and is payable as a lump sum on retirement. If the employee terminates employment with the Company prior to his or her unreduced retirement date, no retirement award is payable. Mr. Blunden and Ms. Tower will be entitled to the retirement award if they continue working for an Emera company until their respective unreduced retirement date. Mr. Balfour, Mr. Bennett and Mr. Marchand are not eligible for a retirement award.

Defined Contribution

The following table shows the changes to accumulated value from January 1, 2020 to December 31, 2020 for the NEO who participated in the Pension Plan on a defined contribution basis.

 

Name     
Accumulated value at
start of year ($)
 
 
    
                Compensatory
change ($)
 
(1) 
   

                Non-compensatory

change ($) (2)

 

 

    

                Accumulated value at end of

year ($)

 

 

Greg Blunden (3)

     883,000        79,000       91,000            1,053,000      

 

(1)

The compensatory change is the value of Company contributions made based on the defined contribution component of the Pension Plan.

 

(2)

The non-compensatory change is the value of employee contributions to the Pension Plan, along with investment earnings.

 

(3)

Mr. Blunden accrues future benefits under the defined contribution component of the Pension Plan and has frozen service under the defined benefit component of the Pension Plan.

Under the defined contribution component of the Pension Plan, the Company contributes a base amount of three per cent of the participant’s eligible earnings into the participant’s account each pay period. Plan participants can also make contributions of up to six per cent of their eligible earnings to the defined contribution component, with the Company matching half of these contributions. Accordingly, the maximum Company contribution to each participant’s defined contribution account, factoring in the base amount and the matching contribution, is six per cent of the participant’s eligible earnings. Canada Revenue Agency limits apply to limit the amount of contributions that can be made under the defined contribution component and, as with the defined benefit component, a portion of the pension a NEO earns in the defined contribution component may be provided under the terms of a Supplementary Retirement Plan.

Mr. Blunden participated in the defined contribution component of the Pension Plan in 2020. Mr. Blunden and the Company each contributed six per cent of his base salary into the Pension Plan up to the total amount permitted under the Income Tax Act, which equated to $13,915 each in 2020. In addition, the Company maintains an account for any Company contributions which would be made in the absence of the Income Tax Act limits, through the Supplementary Retirement Plan. For 2020, the additional Company contribution for Mr. Blunden was $64,995.

 

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Upon ending active employment with the Company at any age between 55 and 65, plan participants in the defined contribution component of the Pension Plan may start receiving retirement income through the purchase of a life annuity or by converting their account to a life income fund.

The defined contribution component of the Pension Plan is administered on behalf of the Company by a major Canadian insurance company, which acts in accordance with the provisions of the defined contribution component of the Pension Plan, the Income Tax Act and the Nova Scotia Pension Benefits Act.

Deferred Share Unit Plan

The Deferred Share Unit (“DSU”) Plan is another component of Emera’s Long-term Incentive Program for senior leaders. A DSU is a notional share unit that is based on the value of an Emera common share – the value of a DSU changes directly in correlation to an Emera share and earns dividend equivalents in the form of additional DSUs. When a dividend is paid on Emera’s common shares, each participant’s DSU account is allocated additional DSUs based on the dividend paid on an equivalent number of Emera common shares. DSUs are not paid out until such time as the participant is no longer employed by the Company or any of its affiliates. When redeemed, the value of a participant’s DSUs is equivalent to the fair market value of an equal number of common shares of the Company.

The DSU Plan is intended to facilitate achievement of share ownership guidelines (discussed in Executive Share Ownership Requirements) without diluting the shareholder base. Prior to the start of each performance year, each plan participant may elect to defer some or all of the short-term incentive payout associated with that performance year in the form of DSUs. When the short-term incentive is paid to the NEOs, the portion elected is allocated to DSUs rather than paid in cash. Since DSUs are principally an income deferral mechanism, there are no performance metrics attributable to DSUs.

Following a participant’s departure from the Company, on a date selected by the participant not later than December 15 of the next calendar year after departure, the value of the participant’s DSUs is calculated by multiplying the number of DSUs in the participant’s account by the average closing Emera common share price for the 50 trading days preceding the payout date (the 50-day average is used to smooth out any short-term price fluctuations). The after-tax amount is paid to the participant. If a participant is a US taxpayer, payment is made six months following the termination date.

In addition, special DSU awards may be made from time to time by the MRCC to selected executives and senior management to recognize singular achievements or the achievement of certain corporate objectives. The MRCC made no such awards to the NEOs in 2020.

2020 DSU Plan Allocations

The table below identifies how much of the short-term incentive for 2020 that each NEO elected to allocate to DSUs:

 

Name     

Percentage of 2020 annual incentive elected to

deferred share units (%)


 

    
                    Dollar amount of 2020 annual  incentive
elected to deferred share units ($)
 
 (1) 

Scott Balfour

     50        710,000  

Greg Blunden

     25        139,160  

Nancy Tower

     100        808,938  

Robert Bennett

     0        0  

Bruce Marchand

     25        108,630  
(1)

The DSU allocations are rounded to the nearest whole unit, so the value of DSUs may vary slightly from the amount of short-term incentive payout allocated.

 

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Executive Share Ownership Requirements and Anti-Hedging Policy

To align the interests of senior management with the interests of shareholders, the Company established share ownership guidelines in 2003 that require designated executives to meet the required ownership level within five years of becoming subject to the guidelines. Mr. Balfour is required to hold shares equal to at least five times his base salary and all other NEOs are required to hold shares equal to at least three times their respective base salaries.

All NEOs are also subject to a one-year post-retirement hold period, which requires the NEOs to maintain a material financial stake in the Company after retirement by holding at least the minimum ownership level of Emera shares for one year after they retire from the Company. This helps maintain a focus on long-term sustainable value and prevents executives from timing their departure to maximize the cash-out value of their equity stake in the Company.

Share ownership is calculated based on: (1) the number of Emera shares an executive owns; and (2) the number of DSUs and RSUs acquired pursuant to the DSU Plan and RSU Plan, which are both considered share equivalents. PSUs and stock options do not count for purposes of the share ownership guidelines. Executives have five years to reach the required ownership level and are required to allocate at least 25 per cent of their short-term incentive payout into DSUs in the first year, and at least 50 per cent every year following, until they meet their target share ownership. If an executive does not meet their ownership target within the required time, the MRCC has the ability to allocate some or all of the executive’s short-term incentive payout to DSUs until the ownership target is met.

Since the purpose of the share ownership requirements is to strengthen the alignment between the interests of senior management and shareholders, the Company has established a robust policy restricting executives from taking any steps that break or otherwise interfere with that alignment. All executives are subject to the Company’s anti-hedging policy, which prohibits them from hedging, pledging, monetizing, or otherwise reducing or limiting their economic risk with respect to any Emera securities they hold, directly or indirectly, including DSUs, RSUs, PSUs, and stock options. These prohibited transactions include short-selling, options, puts and calls, as well as derivatives such as forward contracts, equity swaps, collars and futures, or entering into limited recourse loans secured by securities of Emera.

The share ownership levels for the NEOs are set out below. The values shown are based on the closing price of Emera’s common shares on December 31, 2020 of $54.10. The table does not include the DSUs that will be allocated as part of the 2020 short-term incentive payout, as described in 2020 DSU Plan Allocations.

 

Name     



Required
ownership
level as a
multiple of
base salary
 
 
 
 
 
    

Required
ownership
level ($)
 
 
 
    
DSUs
held (#)
 
 
    
RSUs
held (#)
 
 
    

Value of DSUs
and RSUs
held ($)
 
 
 
    

Common
shares
held (#)
 
 
 
    


Value of
common
shares
held ($)
 
 
 
 
    


Total share
and share
equivalent
ownership ($)
 
 
 
 
    

Multiple
of base
salary
 
 
 (1) 
   


Status
of share
ownership
requirements
 
 
 
 

Scott Balfour

     5.0        5,000,000        88,165        22,889        6,008,031        55,388        2,996,496        9,004,528        9.0       Met  

Greg Blunden

     3.0        1,680,000        43,648        4,614        2,610,975        1,422        76,938        2,687,913        4.8       Met  

Nancy Tower

     3.0        1,875,000        117,615        4,287        6,594,877        58,881        3,185,469        9,780,346        15.6       Met  

Robert Bennett (2)

     3.0        1,911,638        57,693        2,721        3,268,408        4,462        241,368        3,509,775        5.5       Met  

Bruce Marchand

     3.0        1,530,000        31,528        3,735        1,907,729        3,784        204,726        2,112,455        4.1       Met  

 

(1)

Based on executive’s respective base salary as of December 31, 2020.

(2)

Mr. Bennett’s multiple of base salary figure was calculated using the exchange rate of $1.00 USD = $1.3415 CAD, which is based on the Bank of Canada daily average exchange rate between CAD and USD for 2020.

All NEOs have met their required ownership levels. Executives who have not yet attained their required ownership levels are required to allocate at least 50 per cent of their short-term incentive payouts to DSUs until they reach the required ownership level.

 

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Employee Common Share Purchase Plan

Executives are also eligible to participate in the Employee Common Share Purchase Plan, which allows employees of Emera and its affiliates to purchase Emera common shares through regular payroll deductions or lump-sum payments. Participants can contribute up to $20,000 CAD/$15,000 USD per year, and the Company will match 20 per cent on employee contributions up to the contribution limit. The purchase price of the common shares under the Plan is the average of the daily high and low board lot trading price on the TSX for the five trading days prior to the purchase date. At Emera’s option, shares may be purchased instead on the market at prevailing market prices. All common shares purchased under the Plan are immediately vested. Executives participate on the same terms as all other eligible employees.

There are 3,546,270 common shares that remain available for issuance under the Employee Common Share Purchase Plan, which represents approximately 1.4 per cent of the weighted average total issued and outstanding common shares of the Company in 2020.

The table below shows the burn rate ratio for the Employee Common Share Purchase Plan, as defined in the table and measured as a percentage of the weighted average number of shares outstanding for the respective year.

 

      2020 (%)      2019 (%)      2018 (%)  

Burn rate

        

(number of common shares granted in a fiscal year, divided by the number of shares outstanding)

     0.13        0.07        0.10  

The Board may, from time to time, without notice and without shareholder approval, amend, modify, change, suspend or terminate the Employee Common Share Purchase Plan as it, in its absolute discretion, determines appropriate; however, shareholder approval shall be required for any amendment, modification or change that:

 

   

increases the number of common shares reserved for issuance, except an increase made in proportion to an increase in the number of common shares outstanding due to a stock dividend, stock split, amalgamation, reorganization, merger or similar event;

 

   

extends eligibility to participate to non-employee Directors;

 

   

permits rights under the Employee Common Share Purchase Plan to be transferred other than for normal estate settlement purposes;

 

   

permits awards to be granted under the Employee Common Share Purchase Plan in addition to the purchase of common shares using contributions from participants and the Company;

 

   

increases either of the 10 per cent insider participation limits; or

 

   

deletes or reduces the range of amendments which require shareholder approval under this paragraph.

The maximum number of shares issuable to insiders of the Company under all security-based compensation arrangements (including the Stock Option Plan and the Plan) at any time is 10 per cent of the issued and outstanding shares of the Company. The maximum number of shares issued to insiders, within any one-year period, under all security-based compensation arrangements, will not exceed 10 per cent of the issued and outstanding shares of the Company.

The benefits under the Plan are not assignable, and if a Plan participant ceases to be an employee of the Emera Companies their eligibility to participate in the Plan ceases.

Changes to the Employee Common Share Purchase Plan

The Employee Common Share Purchase Plan has been in place since 1995 and approximately 2,000 employees currently participate in the Plan. In 2019, the Company conducted a review of the Employee Common Share Purchase Plan to assess its competitiveness against market, which indicated that the Plan’s contribution limits and company match were below market. The participation rates of employees, particularly in the US, were also lower than many other companies that offer similar share purchase programs.

 

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Given the intention of the Employee Common Share Purchase Plan is to encourage employees to become shareholders of Emera, which in turn creates an alignment of interests between shareholders and employees, the Company believes it is important to encourage employees to participate in the Plan. Moreover, since the Plan is treasury based, it has the added benefit of acting as a source of capital for the Company. Accordingly, the Company made the following amendments to the Plan, none of which required shareholder approval under the terms of the Plan, and which took effect in 2020:

 

Change    Old plan terms    New plan terms
Eligible participants    All regular full-time and part-time employees    Those classes of employees designated by the MRCC
TFSAs    No ability to hold shares in a Tax-Free Savings Account (“TFSA”)    Canadian participants may hold shares in a TFSA account and transfer shares between their regular account and TFSA account
Maximum employee contribution    $8,000 CAD per year    $20,000 CAD/$15,000 USD per year
Minimum employee contribution    $25 per month    Payroll deduction of $25 per month and lump sum contribution of $75
Company match    20 per cent on employee contributions up to $3,000, and 10 per cent on contributions between $3,000 and $8,000    20 per cent on employee contributions up to the contribution limit of $20,000 CAD/$15,000 USD
Dividend reinvestment    Dividend reinvestment was provided only to Canadian resident participants; other participants received dividends in cash    Dividend reinvestment applies to all participants except where not permitted by law
Price of shares on reinvestment of dividends    Price of shares purchased with dividends was the average of daily high and low board lot trading prices of the Company’s shares on the TSX for the five trading days immediately preceding the end of each quarter    The price of shares on reinvestment of dividends is the average of the closing trading prices on the TSX of the Company’s shares for five trading days immediately preceding the dividend payment date
Company match on dividends    Company match applied to reinvested dividends    No Company match on dividends
Clarifying provisions        

•  MRCC oversight authority and delegation power clarified;

•  Details added on the sale or withdrawal of shares held under the Plan;

•  Clarified treatment of employee contributions and Plan shares upon termination of employment;

•  Clarified details on tax consequences of participation;

•  Added ability of participants to designate a beneficiary in the event of death under TFSA Account;

•  Added standard clauses addressing (a) participant responsibility for fees on sale of shares; (b) requirement for participant instructions in the case of an issuer bid, takeover bid or other transaction; (c) sale and reinvestment of any warrants, options or other rights received on Plan shares; (d) adjustments in connection with changes in the Company’s share capitals; and (e) electronic communications; and

•  Other minor changes to improve clarity and consistency in the use of terms.

 

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The Company believes the above changes strike an appropriate balance between making the Employee Common Share Purchase Plan more competitive and increasing employee participation rates with managing the costs of the Plan.

Other Executive Benefits

The Company provides executives with additional benefits in accordance with the compensation program objectives. As part of their compensation and consistent with market practice, executives, including the NEOs, are eligible to receive:

 

   

annual income tax return preparation;

 

   

monthly parking;

 

   

monthly car allowance plus mileage, as applicable; and

 

   

annual wellness/fitness allowance.

In all cases, the above entitlements are bundled into an annual perquisite allowance, which is paid out in cash in equal instalments over the course of the year and reviewed on an annual basis.

For employees who are assigned to work outside of their home country, the Company provides allowances to reflect differentials in the cost of goods and housing between the executive’s home location and the location to which they are assigned. The allowances are determined using a third-party data provider and are reviewed at least on an annual basis and can be adjusted upward or downward based on prevailing cost differentials and exchange rates. Employees on assignment may also receive a travel allowance to allow the employees and their dependants to maintain ties and relationships in their home country.

These benefits are considered taxable benefits and are reported in the Summary Compensation Table for the NEOs.

 

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Termination and Change of Control Benefits

The following table provides the estimated amounts of incremental payments, payables and benefits to which each NEO would be entitled based on differing departure scenarios – resignation, termination for cause, termination without cause, separation from the Company in circumstances of a change of control, and retirement, assuming the triggering event took place on December 31, 2020.

 

Name     

Departure

scenario 

 

(1) 

   
Cash
severance ($)
 
 
    
Short-term
incentive ($)
 
 
    

Performance
share units
(PSUs) ($)
 
 
 (2) 
    

Restricted
share units
(RSUs) ($)
 
 
 (2) 
    
Stock
options ($)
 
 
    


Continuation
of benefits

(present
value) ($)

 
 

 
 (3) 

     Total ($)  

Scott Balfour

     Resignation                                                  

Termination for cause

 

                                               

Termination without cause

 

    2,000,000        2,000,000        3,594,443        435,874               5,719        8,036,036  
                                 Control change       2,000,000        2,000,000        6,699,087        1,307,622        2,605,793        5,719        14,618,221  
       Retirement                                                  

Greg Blunden

     Resignation                                                  
     Termination for cause                                                  
     Termination without cause       560,000        392,000        809,221        87,864               4,874        1,853,959  
     Control change       560,000        392,000        809,221        87,864        699,125        4,874        1,853,959  
       Retirement                                                  

Nancy Tower

     Resignation                                                  
     Termination for cause                                                  
     Termination without cause       625,000        437,500        791,713        81,637               2,544        1,938,394  
     Control change       625,000        437,500        1,432,710        244,911        778,385               2,740,121  
       Retirement                                                  

Robert Bennett (4)

     Resignation                                                  
     Termination for cause                                                  
     Termination without cause       637,213        382,328        694,677        69,511               5,916        1,789,645  
     Control change       637,213        382,328        1,250,280        208,533        589,183               2,478,354  
       Retirement                                                  

Bruce Marchand

     Resignation                                                  
     Termination for cause                                                  
     Termination without cause       767,500        459,000        648,247        71,125               3,984        1,949,856  
     Control change       767,500        459,000        648,247        71,125        588,510        3,984        1,949,856  
       Retirement                                                  

 

(1)

Please see the tables following for a description of the entitlements of each NEO under the various departure scenarios.

(2)

Payouts for PSUs assume a performance factor of 1.0 and both PSUs and RSUs are valued using the average closing share price for the last 50 trading days of 2020 ($54.66).

(3)

Continuation of benefits may reflect amounts for health and dental benefits and insurance benefits, pursuant to the terms of the NEOs’ employment contracts, as applicable.

(4)

Any USD amounts applicable to Mr. Bennett have been converted to CAD using the exchange rate of $1.00 USD = $1.3415 CAD, which is based on the Bank of Canada daily average exchange rate between CAD and USD for 2020.

 

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The following is a summary of each NEO’s entitlements on departure, based on his or her employment contract or the applicable plans as of December 31, 2020.

 

Scott Balfour

Resignation    All unvested PSUs, RSUs and stock options are forfeited.
Terminated for cause    All unvested PSUs, RSUs and stock options are forfeited.
Terminated without cause    Entitled to a lump sum equal to 24 months’ compensation based upon annual salary and short-term incentive at target. Health, dental and other such benefits will be continued for up to 12 months. Unvested PSUs and RSUs are prorated to the date of termination and paid out at the end of the respective performance period, subject to the achievement of the applicable performance criteria. Unvested stock options are forfeited.
Change of control    If there is a change of control of the ownership of the Company and Mr. Balfour’s employment is terminated without cause or Mr. Balfour terminates his employment for “good reason” as defined in his employment agreement and below, within 24 months of the change of control, Mr. Balfour is entitled to receive 24 months’ compensation based upon annual salary and short-term incentive at target. Health, dental and other such benefits will be continued for up to 12 months. Unvested PSUs and RSUs that were granted prior to the change of control are deemed to vest on the termination date and are paid out assuming a performance factor of 1.0. Unvested stock options that were granted prior to the change of control are deemed to vest on the termination date and must be exercised by the earlier of (a) six months from the termination date; and (b) 10 years from the original grant date.
Retirement   

Mr. Balfour becomes eligible to retire with an unreduced pension as of April 30, 2027. Information regarding pension entitlement is contained in Pension Plan Benefits. PSUs and RSUs continue to be eligible to vest for two years following retirement in accordance with the applicable performance criteria.

 

Unvested stock options continue to be eligible to vest for two years past retirement. All vested stock options must be exercised by the earlier of (a) 27 months from the date of retirement; and (b) 10 years from the original grant date.

 

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Greg Blunden

Resignation    All unvested PSUs, RSUs and stock options are forfeited.
Terminated for cause    All unvested PSUs, RSUs and stock options are forfeited.
Terminated without cause    Entitled to a lump sum equal to 12 months’ compensation based upon annual salary and short-term incentive at target. Health, dental and other such benefits will be continued for up to 12 months. Unvested PSUs and RSUs are prorated to the date of termination and paid out assuming a performance factor of 1.0. Unvested stock options are forfeited.
Change of control    If there is a change of control of the ownership of the Company, such that any one party acquires 50 per cent or more of voting securities Mr. Blunden may elect to terminate employment for “good reason”, as defined below, within three months of such changes and receive 12 months’ compensation based upon annual salary and short-term incentive at target. Health, dental and other such benefits will be continued for up to 12 months. Unvested PSUs and RSUs are prorated to the date of termination and paid out assuming a performance factor of 1.0. Should the executive terminate their employment for “good reason” as defined in the Senior Management Stock Option Plan, unvested stock options that were granted prior to the change of control are deemed to vest on the termination date and must be exercised by the earlier of (a) six months from the termination date; and (b) 10 years from the original grant date.

Retirement

   Mr. Blunden becomes eligible to retire with an unreduced pension as of December 31, 2024. Information regarding pension entitlement is contained in Pension Plan Benefits. PSUs and RSUs continue to be eligible to vest in accordance with the applicable performance criteria and will be paid out on a prorated basis upon vesting. Unvested stock options continue to be eligible to vest for two years past retirement. Any stock options that have not vested within two years of retirement are forfeited. All vested stock options must be exercised by the earlier of (a) two years from the date of retirement; and (b) 10 years from the original grant date.

 

Nancy Tower

Resignation    All unvested PSUs, RSUs and stock options are forfeited.
Terminated for cause    All unvested PSUs, RSUs and stock options are forfeited.
Terminated without cause    Entitled to a lump sum equal to 12 months’ compensation based upon annual salary and short-term incentive at target. Health, dental and other such benefits will be continued for up to 12 months. Unvested PSUs and RSUs are prorated to the date of termination and paid out based on an estimated future value. Unvested stock options are forfeited.
Change of control    If there is a change of control of the ownership of the Company, such that any one party acquires 50 per cent or more of voting securities, Ms. Tower may elect to terminate employment for “good reason”, as defined below, within three months of such changes and receive 12 months’ compensation based upon annual salary and short-term incentive at target. Should the executive terminate their employment for “good reason” as defined below and in the Senior Management Stock Option Plan, unvested PSUs and RSUs are deemed to vest on the termination date. Unvested stock options that were granted prior to the change of control are deemed to vest on the termination date and must be exercised by the earlier of (a) six months from the termination date; and (b) 10 years from the original grant date.
Retirement    Ms. Tower became eligible to retire with an unreduced pension as of March 31, 2019. Information regarding pension entitlement is contained in Pension Plan Benefits. PSUs and RSUs continue to be eligible to vest for two years following retirement in accordance with the applicable performance criteria. Unvested stock options continue to be eligible to vest for two years past retirement. Any stock options that have not vested within two years of retirement are forfeited. All vested stock options must be exercised by the earlier of (a) two years from the date of retirement; and (b) 10 years from the original grant date.

 

        “Good

reason” is described as any of the following events occurring without the NEO’s consent:

 

   

the Company materially diminishes the NEO’s position, authority, duties or responsibilities;

 

   

the Company requires the NEO to be based at a location more than 50 km from his or her current work location or to travel to a significantly greater extent; or

 

   

the Company materially reduces the NEO’s annual base salary or his or her target incentive awards.

 

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Robert Bennett

Resignation    All unvested PSUs, RSUs and stock options are forfeited.
Terminated for cause    All unvested PSUs, RSUs and stock options are forfeited.
Terminated without cause    Entitled to a lump sum equal to 12 months’ compensation based upon annual salary and short-term incentive at target. Health, dental and other such benefits will be continued for up to 12 months. Unvested PSUs and RSUs are prorated to the date of termination and paid out based on an estimated future value. Unvested stock options are forfeited.
Change of control    If there is a change of control of the ownership of the Company, such that any one party acquires 50 per cent or more of voting securities, Mr. Bennett may elect to terminate employment for “good reason”, as defined below, within three months of such changes and receive 12 months’ compensation based upon annual salary and short-term incentive at target. Should the executive terminate their employment for “good reason” as defined below and in the Senior Management Stock Option Plan, unvested stock options that were granted prior to the change of control are deemed to vest on the termination date and must be exercised by the earlier of (a) six months from the termination date; and (b) 10 years from the original grant date.
Retirement    Mr. Bennett became eligible to retire with an unreduced pension as of October 31, 2017. Information regarding pension entitlement is contained in Pension Plan Benefits. PSUs and RSUs continue to be eligible to vest for two years following retirement in accordance with the applicable performance criteria. Unvested stock options continue to be eligible to vest for two years past retirement. Any stock options that have not vested within two years of retirement are forfeited. All vested stock options must be exercised by the earlier of (a) two years from the date of retirement; and (b) 10 years from the original grant date.

 

Bruce Marchand

Resignation    All unvested PSUs, RSUs and stock options are forfeited.
Terminated for cause    All unvested PSUs, RSUs and stock options are forfeited.
Terminated without cause    Entitled to a lump sum equal to 18 months’ compensation based upon annual salary and short-term incentive at target. Health, dental and other such benefits will be continued for up to 12 months. Unvested PSUs and RSUs are prorated to the date of termination and paid out based on an estimated future value. Unvested stock options are forfeited.
Change of control    If there is a change of control of the ownership of the Company, such that any one party acquires 50 per cent or more of voting securities, Mr. Marchand may elect to terminate employment for “good reason”, as defined below, within three months of such changes and receive 18 months’ compensation based upon annual salary and short-term incentive at target. Health, dental and other such benefits will be continued for up to 12 months. Unvested PSUs and RSUs are prorated to the date of termination and paid out based on an estimated future value. Should the executive terminate their employment for “good reason” as defined below and in the Senior Management Stock Option Plan, unvested stock options that were granted prior to the change of control are deemed to vest on the termination date and must be exercised by the earlier of (a) six months from the termination date; and (b) 10 years from the original grant date.
Retirement    Mr. Marchand becomes eligible to retire with an unreduced pension as of June 30, 2022. Information regarding pension entitlement is contained in Pension Plan Benefits. PSUs and RSUs continue to be eligible to vest for two years following retirement in accordance with the applicable performance criteria. Unvested stock options continue to be eligible to vest for two years past retirement. Any stock options that have not vested within two years of retirement are forfeited. All vested stock options must be exercised by the earlier of (a) two years from the date of retirement; and (b) 10 years from the original grant date.

 

        “Good

reason” is described as any of the following events occurring without the NEO’s consent:

 

   

the Company materially diminishes the NEO’s position, authority, duties or responsibilities;

 

   

the Company requires the NEO to be based at a location more than 50 km from his or her current work location or to travel to a significantly greater extent; or

 

   

the Company materially reduces the NEO’s annual base salary or his or her target incentive awards.

 

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Shares Authorized for Issuance Under Equity-based Compensation Plans

The following table shows shares authorized for issuance under the Stock Option Plan and the Employee Common Share Purchase Plan as of December 31, 2020. There are no equity-based compensation plans that were not approved by shareholders.

 

      (A)      (B)      (C)  
Plan category    Number of shares to be
issued upon exercise of
outstanding options
     Weighted average
exercise price of
outstanding options ($)
    

Number of shares available  

for future issuance under  

equity compensation plans  

(excluding column (A))  

 

Equity-based compensation plans approved by shareholders

        

•Senior Management Stock Option Plan

     2,267,782        46.62        1,262,110    

•Employee Common Share Purchase Plan

     N/A        N/A        3,546,270    

Total

     2,267,782        46.62        4,808,380    

Loans to Directors and Officers

No current or former Directors, officers or employees of Emera, or any of its subsidiaries, had any loans with Emera or any of its subsidiaries during the most recently completed financial year, other than routine indebtedness previously outstanding as defined under Canadian securities laws.

Material Transactions

During the most recently completed financial year, insiders of the Company and its affiliates, including Directors, executive officers, proposed Director nominees or their associates or corporations they controlled, did not have any material interest, direct or indirect, in any transaction or in any proposed transaction that has materially affected or will materially affect the Company.

Management Contracts

There are no functions of management that are performed by a person or company other than the Directors, executive officers or other employees of the Company.

Audit Committee Information

For information regarding Emera’s Audit Committee, including its Charter, composition, relevant education and experience of its members, Audit Committee oversight, policies and procedures for the approval of non-audit services and Auditors’ service fees, please refer to Emera’s Annual Information Form, available on SEDAR at www.sedar.com, or by contacting the Corporate Secretary of the Company.

 

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Appendix A

EMERA INCORPORATED BOARD OF DIRECTORS CHARTER

The fundamental responsibility of the Board of Directors (the “Board”) is to provide stewardship and governance to Emera Incorporated (“Emera”) for the long-term success of the Company by overseeing management of the business.

In addition to the powers set out in Emera’s Articles of Association, the Board shall have the following duties and responsibilities.

STRATEGIC PLANNING

The Board shall provide oversight and guidance on the strategic issues facing Emera.

The Board shall oversee a strategic planning process resulting in a strategic plan which shall be approved on an annual basis and will take into account, among other things, the opportunities and risks of the business.

The Board shall regularly consider Emera’s strategy, evaluate progress made in pursuing that strategy, and consider any adjustments to the strategy that may be required from time to time.

The Board shall review and approve the Company’s financial objectives, plans and actions, including significant capital allocations and expenditures.

The Board shall review and approve all material acquisitions, dispositions, projects, business plans, and budgets.

CULTURE

The Board shall oversee management’s approach to addressing Emera’s Environmental, Social and Governance (“ESG”) impacts, risks and opportunities which are most important to its business performance and to key stakeholders.

The Board shall be comprised of a majority of “independent directors” as defined from time to time under applicable legislation and the rules of any stock exchange on which Emera’s securities are listed for trading.

The Chair shall be an “independent director” as defined above.

The Board shall review and approve standards for ethical business conduct for employees, officers and directors of Emera and its subsidiaries and affiliates and a procedure for monitoring compliance with such code throughout the Company.

The Board shall satisfy itself as to the integrity of the Chief Executive Officer and executive officers and management’s creation of an integrity-based culture throughout the Company.

RISK RESPONSIBILITY

The Board shall oversee the implementation by management of appropriate systems to identify, report, and manage the principal risks of Emera’s business. The Board will consider Emera’s risk profile and oversee Emera’s risk management by reviewing:

 

  (a)

the regular identification and assessment of the principal risks of Emera;

  (b)

the process for ongoing monitoring and reporting of the principal risks of Emera;

  (c)

the effectiveness of Emera’s mitigation response to its principal risks;

  (d)

the alignment of risk management with Emera’s risk profile, its strategy, and its organizational objectives, including capital and resources allocation.

The Board shall also review Emera’s annual insurance program and uninsured exposure and Emera’s business continuity and disaster recovery plans.

The Board shall receive regular updates on the status of risk management activities and initiatives.

The Board shall review management’s processes that provide reasonable assurance of compliance with applicable legal and regulatory requirements.

 

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LEADERSHIP AND SUCCESSION

The Board shall oversee policies and practices to enable the Company to attract, develop and retain the human resources required by the Company to meet its business objectives.

The Board shall appoint executive officers and delegate the necessary authority for the conduct of the business.

The Board shall establish annual performance expectations and corporate goals and objectives for the Chief Executive Officer and monitor progress against those expectations.

The Board shall evaluate the performance, and, following a review of recommendations from the Management Resources and Compensation Committee, approve compensation for executive officers.

The Board shall oversee the succession planning program for the Chief Executive Officer and other key executive positions from time to time.

FINANCIAL

The Board shall oversee the financial reporting and disclosure obligations imposed on the Company by laws, regulations, rules, policies and other applicable requirements.

The Board will review the financial performance of the Company and declare dividends as appropriate.

The Board shall approve for release to the public as necessary the Company’s financial statements, management’s discussion and analysis (“MD&A”) and earnings releases prepared by management and oversee the Company’s compliance with applicable audit, accounting and reporting requirements.

The Board shall review the quality and integrity of Emera’s internal controls and management information systems.

CORPORATE COMMUNICATIONS AND PUBLIC DISCLOSURE

The Board shall review and approve a formal corporate disclosure policy and oversee policies and processes for accurate, timely and appropriate public disclosure.

The Board shall oversee systems for receiving feedback from stakeholders and review such feedback received by the Company.

GOVERNANCE RESPONSIBILITY

The Board is responsible for overseeing the Company’s corporate governance policies and practices and shall maintain a set of corporate governance practices that are specifically appropriate to the Company.

Pursuant to the Articles, the directors shall appoint one of the directors as Chair of the Board and such director shall not be an employee of Emera or any of its affiliates or subsidiaries.

The Board shall establish appropriate structures and procedures to allow the Board to function independently of management and in the interests of the Company and its shareholders.

The Board, in carrying out its mandate, shall appoint committees of the Board and delegate certain functions to those committees, each of which shall have its own written charter. Notwithstanding such delegation, the Board retains its oversight function and ultimate responsibility for these delegated functions.

The Board shall oversee a process for the selection of qualified individuals for board nomination and shall approve selection criteria for identifying director candidates taking into account the competencies and skills the Board as a whole should possess.

The Board shall undertake regular evaluation of the Board, the Chair of the Board, the Board committees and individual Directors. The Board shall undertake regular evaluation of Directors’ compensation.

The Board shall review this Charter annually to ensure it appropriately reflects the Board’s stewardship responsibilities.

 

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Appendix B

EMERA INCORPORATED (THE “COMPANY”)

RESOLUTION AMENDING THE SENIOR MANAGEMENT STOCK OPTION PLAN

MAY 20, 2021

RESOLVED THAT:

 

1)

The Senior Management Stock Option Plan (the “Plan”) of the Company be amended to increase by 3,000,000 the maximum number of common shares of the Company (“Common Shares”) that can be issued under the Plan from 11,700,000 to 14,700,000 Common Shares.

 

2)

Any Director or Officer of the Company be and is hereby authorized and directed to execute, whether under the corporate seal of the Company or otherwise, and to deliver all documents or instruments in writing and to do all such other acts and things as may be determined necessary or appropriate to carry out the terms of this resolution, the making of such determination to be conclusive evidence of the necessity or appropriateness.

 

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LOGO


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LOGO

Exhibit 99.2

 

 


 

 


 

We’re a team of experts focused on safely delivering cleaner, affordable and reliable energy to our over 2.5 million customers in Canada, the US and the Caribbean. Our Environmental, Social and Governance (ESG) commitments are core to our strategy and our culture. We’re leading the way to a cleaner energy future with clear climate goals and a vision to achieve net-zero carbon emissions by 2050. We primarily invest in regulated electric and gas utilities, driving predictable returns and steady growth for our investors, enabling us to reinvest in our teams, our companies and communities.

 



 
OUR CLIMATE COMMITMENT

 

 

 

EMERA 2020 ANNUAL REPORT 1


 

 


 

WHY INVEST IN EMERA

 

         
FINANCIAL        
4-5%   $7.4B-$8.6B   7.5-8.5%
dividend growth target through to 2022   capital investment plan through 2023   rate base growth through 2023
         
         
OPERATIONAL        
1,262 MW   1.4M   1,250 MW
installed renewable capacity   smart meters to be installed by 2022; 1M+ already complete   solar capacity at Tampa Electric by 2023; 630MW installed since 2016
         
         
ENVIRONMENTAL        
39%   68%   60%
reduction in CO2 emissions from 20051   reduction in our use of coal in generation from 2005   of capital plan to 2023 invested in decarbonization and reliability
         
         
COMMUNITY        
$16M   40,470 HOURS   $5M
invested in our communities   volunteered by Emera employees   Inclusion & Diversity Community Fund established
         
         
SAFETY AND EMPLOYEES        
25%   41%   32%
reduction in OSHA injury rate   of senior leaders at Emera Inc. are women; 34% across Emera2   reduction in Lost Time Injury Rate
         
237       Top 100 Employer
Proactive Rate (PAIR) – the number of proactive safety reports per 100 employees       in Canada for 3rd consecutive year
         
         
GOVERNANCE        
36%   99%   100%
of Director Nominees are women, including the Chair   shareholder support for 2020 Say on Pay vote   of employees completed annual Code of Conduct training
         

 

1 Up from 36% in 2019.

2 Senior leaders includes Director level and above.

 

Data is as of Dec. 31, 2020, unless otherwise indicated.

 

EMERA 2020 ANNUAL REPORT 3


 

Letter from the Chair and the CEO

 

Fellow shareholders,

 

Despite the extraordinary and unexpected challenges of the global COVID-19 pandemic, we are proud of what the team accomplished in 2020 for our customers, communities, and shareholders. Our ability to adapt and deliver the essential energy our customers count on, perhaps now more than ever, is a testament to the strength and resiliency of our teams and our strategy.

 

COVID RESPONSE 

Our commitment to health and safety is core to our pandemic planning and our continued response to COVID-19. Last year, our teams adapted quickly to add new protocols and procedures to continue to safely deliver the cleaner, affordable and reliable energy our customers count on.

 

Our teams also supported our customers and communities through customer relief programs and community investments to help those most impacted by the pandemic. Across Emera’s operating companies, we contributed over $6 million to organizations providing critical aid, including assistance with energy costs, food, shelter and mental health support.

FINANCIAL RESULTS

We delivered solid financial results in 2020. Our annual adjusted earnings per share (EPS) were in line with our expectations and grew by three per cent to $2.68. It’s notable that the asset sales we completed over the past two years distort the actual year-over-year comparison of the performance of our business. If we adjust our EPS for the operating earnings impact of asset sales, our 2020 results were 15 per cent higher than those in 2019, principally driven by the 13 per cent year-over-year earnings growth from the continuing portion of our portfolio of regulated businesses.

 

The strong performance of our regulated utilities supported the four per cent increase to our dividend, keeping our commitment to providing predictable, sustainable and growing value to our investors. We continue to target 4–5 per cent dividend growth through to 2022.

 

We also strengthened our balance sheet – completing our asset sale program with the sale of Emera Maine in the first quarter, as well as by retiring $390 million of holding company debt and raising $490 million of common equity. We also solidified our future earnings and cash flow growth and quality with the rate case settlements secured by Peoples Gas and New Mexico Gas.



 

 

4 EMERA 2020 ANNUAL REPORT


 

LETTER FROM THE CHAIR AND THE CEO

 

 

 

Photos: (Left) A technician installing solar panels at Big Bend as part of the 630MW of solar we’ve put into service at Tampa Electric since 2016. Another 600MW will be complete by 2023. (Centre) A member of the Nova Scotia Power team at the Digby Neck Wind Farm. At 18 per cent, NSP has one of the highest integrations of wind in North America. (Right) A People’s Gas employee performs maintenance at a transmission gate station in Florida. Natural gas is an important source of cleaner energy as we focus on eliminating coal by 2040.

 

In the capital markets, regulated utility stocks, including Emera, did not perform as well as we might have expected given the stable financial performance within an environment of lower interest rates and economic uncertainty for much of the year – typically conditions when regulated utility stocks would outperform. Emera and our peers underperformed as investors preferred other sectors. As a result, while our total shareholder return for the year was consistent with our regulated utility peers in Canada and the US, it was lower than both the TSX Capped Utilities Index and TSX Composite. Despite the share performance of our industry in 2020, Emera’s longer-term total shareholder return continued to provide consistent and competitive value to our investors, delivering 10 per cent returns over the past three, five and ten years.

 

PROVEN STRATEGY

Our strategy is designed to deliver for our customers and shareholders today and prepare for an energy future that is being shaped by the customer-driven trends of decarbonization, decentralization and digitalization.

 

For over 15 years, we’ve been focused on safely delivering cleaner, affordable, reliable energy for our customers. By delivering for our customers, we are driving predictable returns and steady growth for our investors, enabling us to reinvest in our teams, companies, and communities.

STRATEGY IN ACTION

Even with the challenges of the pandemic and additional protocols in place, we continued to advance our strategy and our capital program, executing $2.7 billion in capital in 2020, more than any other year in our history. Our large capital projects remained on time and on budget.

 

As Florida’s top producer of solar energy per customer, Tampa Electric completed construction of the final phase of its first 600MW of solar, putting six million solar panels into service over the last three years. And we started work on another 600MW to be put into service in 2023. Within two years, nearly 14 per cent of Tampa Electric’s energy will come from the sun – enough to power more than 200,000 homes.

 

The team at Tampa Electric made significant progress on the $850M USD modernization of Big Bend facility, and remains on budget and on track for putting the gas generators into service in “simple cycle” mode at the end of this year, further reducing our use of coal. When complete in 2023, this project will have state-of-the-art, highly efficient, combined-cycle natural gas units, capable of producing 1,090MW of electricity.


EMERA 2020 ANNUAL REPORT 5


 

 


 

LETTER FROM THE CHAIR AND THE CEO

 

“By delivering for our customers, we are driving predictable returns and steady growth for our investors, enabling us to reinvest in our teams, companies, and communities.”

 

We continued our deployment of next generation automatic meter infrastructure (smart meters) to electric utility customers in Florida, Barbados and Nova Scotia with over a million now in service. Smart meters provide our customers with greater access to information about energy use and they will eventually help us with faster restoration times. Across Emera, we will install roughly 1.4 million smart meters by 2022.
The team at New Mexico Gas completed the Santa Fe Loop project. This was the largest pipeline expansion in the history of the company, significantly increasing capacity and reliability for customers.
We advanced the Clean Energy Bridge project in Barbados, a new 33MW generation facility that will serve as critical generation capacity, delivering affordable and reliable energy for customers, as we continue to champion and build renewables and transition to a 100 per cent clean energy future in Barbados. Construction is expected to be complete later this year.
We launched Emera Technologies’ BlockEnergy microgrid solution, an innovative, utility-owned platform that integrates rooftop solar, energy storage and smart controls. BlockEnergy creates independent clean energy networks and maximizes reliability by also being fully connected to the power grid. BlockEnergy was developed in partnership with Sandia National Labs and has been successfully demonstrated and tested at the US Air Force Base in Albuquerque, New Mexico. BlockEnergy is now advancing to a full-scaled pilot as it is currently being installed for 37 homes in a residential community under construction in the Tampa, Florida area.

ENVIRONMENTAL, SOCIAL AND GOVERNANCE (ESG)

Our Environmental, Social and Governance (ESG) commitments have been core to our strategy and our culture for more than 15 years. Last year, in addition to advancing our ESG commitments, we also enhanced our ESG reporting with the addition of two new disclosure frameworks. We also reinforced our ESG governance by appointing executive oversight of ESG and establishing a Sustainability Management Committee to oversee our ESG risk management, disclosures and focus areas.

 

We will be releasing our 2020 Sustainability Report later this year. Previous reports are available on our website.

 

Decarbonization and 2050 Net-Zero Vision

Decarbonization is central to our strategy and a key driver of our growth. For more than 15 years we’ve been working to reduce CO2 emissions from across our operations, and in 2020 we achieved a 39 per cent reduction over 2005 levels. We recently announced our Climate Commitment – building on our strong decarbonization track record by setting clear future-focused carbon reduction goals and a vision to achieve net-zero carbon emissions by 2050. With existing technologies and resources and the benefit of supportive regulatory decisions, we plan and expect to achieve the following goals compared to corresponding 2005 levels:

 

A 55 per cent reduction in carbon emissions by 2025.
An 80 per cent reduction in coal usage by 2023 and the retirement of our last existing coal unit no later than 2040.
At least an 80 per cent reduction in carbon emissions by 2040.

 

We’re seeking to achieve these goals and realize our net-zero vision while staying focused on enhancing reliability, maintaining affordability, adopting emerging technologies and working constructively with policymakers, regulators, partners, investors, and our communities.



EMERA 2020 ANNUAL REPORT 7


 

LETTER FROM THE CHAIR AND THE CEO

 

Inclusion and Diversity

We know diverse cultures and experiences make our business stronger. We are committed to providing diverse and inclusive workplaces where everyone is valued and treated with respect. We continue to execute on our multi-year Inclusion and Diversity Strategy to align best practices and drive key areas of focus and improvement. We continually assess and address pay equity gaps, conduct training for all Emera leaders and Board members, cultivate strong I&D employee networks, gather self-identification data to ensure our teams reflect the communities where we operate, integrate our commitment to diversity into our recruitment and advancement strategies and we recently established a $5 million fund to support inclusion and diversity efforts in our communities. We’ve made good progress, but we know there is more work to be done.

 

Safety

In 2020, we made good progress on our safety performance and reinforcing our strong safety culture. We implemented our company-wide safety management system and achieved the lowest Occupational Safety & Health Association (OSHA) and Lost Time Injury rates in our history. However, recent contractor fatalities serve as tragic reminders that our work in this area is never done. We’re more resolved than ever to achieve an Emera where no one gets hurt.

BOARD OF DIRECTORS

Sylvia Chrominska, a valued member of our Board since 2010, is stepping down this year. Sylvia has made significant contributions to our Board, particularly as a member of the Management Resources and Compensation Committee, and as committee Chair since 2016. In this role, she provided exceptional guidance and oversight to Emera’s human resources strategy and compensation practices. Thank you, Sylvia. On behalf of all of us, you will be missed.

 

We would also like to welcome Karen Sheriff, who joined our Board in February 2021. Karen brings cross-industry leadership experience, along with her extensive expertise in driving innovation and corporate strategy. Karen is a valuable addition to our Board.

 

THANK YOU

With a strong team and proven strategy, Emera is well positioned for future growth.

 

To the Board of Directors and the entire Emera team, thank you for your ongoing commitment to a strong and stable Emera. To our valued shareholders, thank you for your continued support.



 

   
   
Jackie Sheppard Scott Balfour
Chair, Emera Inc. Board of Directors President and Chief Executive Officer, Emera Inc.

 

8 EMERA 2020 ANNUAL REPORT


 

FINANCIAL REVIEW

 

Forward-looking Information 11
Introduction and Strategic Overview 11
Non-GAAP Financial Measures 13
Consolidated Financial Review 15
Significant Items Affecting Earnings 15
Consolidated Financial Highlights by Business Segment 16
Consolidated Income Statement Highlights 17
Business Overview and Outlook 20
COVID-19 Pandemic 20
Florida Electric Utility 22
Canadian Electric Utilities 23
Other Electric Utilities 25
Gas Utilities and Infrastructure 26
Other 27
Consolidated Balance Sheet Highlights 28
Developments 29
Outstanding Stock Data 30
Financial Highlights 31
Florida Electric Utility 31
Canadian Electric Utilities 34
Other Electric Utilities 37
Gas Utilities and Infrastructure 40
Other 43
Liquidity and Capital Resources 45
Consolidated Cash Flow Highlights 46
Working Capital 47
Contractual Obligations 48
Forecasted Gross Consolidated Capital Expenditures 49
Debt Management 49
Credit Ratings 51
Share Capital 51
Pension Funding 51
Off-Balance Sheet Arrangements 52
Dividend Payout Ratio 52
Transactions with Related Parties 53
Enterprise Risk and Risk Management 53
Risk Management including Financial Instruments 63
Disclosure and Internal Controls 65
Critical Accounting Estimates 66
Changes in Accounting Policies and Practices 70
Future Accounting Pronouncements 71
Summary of Quarterly Results 72
Management Report 73
Independent Auditor’s Report 74
Report of Independent Registered Public Accounting Firm 78
Consolidated Financial Statements 81
Notes to the Consolidated Financial Statements 87
Emera Leadership and Board 159
Shareholder Information 160


 

EMERA 2020 ANNUAL REPORT 9


 

MANAGEMENT’S DISCUSSION & ANALYSIS

 

MANAGEMENT’S DISCUSSION & ANALYSIS

 

As at February 16, 2021

 

Management’s Discussion & Analysis (“MD&A”) provides a review of the results of operations of Emera Incorporated and its subsidiaries and investments (“Emera”) during the fourth quarter of 2020 relative to the same quarter in 2019; the full year of 2020 relative to 2019 and selected financial information for 2018; and its financial position as at December 31, 2020 relative to December 31, 2019. Throughout this discussion, “Emera Incorporated”, “Emera” and “Company” refer to Emera Incorporated and all of its consolidated subsidiaries and investments. The Company’s activities are carried out through five reportable segments: Florida Electric Utility, Canadian Electric Utilities, Other Electric Utilities, Gas Utilities and Infrastructure, and Other.

 

This discussion and analysis should be read in conjunction with the Emera Incorporated annual audited consolidated financial statements and supporting notes as at and for the year ended December 31, 2020. Emera follows United States Generally Accepted Accounting Principles (“USGAAP” or “GAAP”).

 

The accounting policies used by Emera’s rate-regulated entities may differ from those used by Emera’s non-rate-regulated businesses with respect to the timing of recognition of certain assets, liabilities, revenues and expenses. At December 31, 2020, Emera’s rate-regulated subsidiaries and investments include: 

 

Emera Rate-Regulated Subsidiary or Equity Investment Subsidiary Accounting Policies Approved/Examined By
Tampa Electric – Electric Division of Tampa Electric Company (“TEC”) Florida Public Service Commission (“FPSC”) and the Federal Energy Regulatory Commission (“FERC”)
Nova Scotia Power Inc. (“NSPI”) Nova Scotia Utility and Review Board (“UARB”)
Barbados Light & Power Company Limited (“BLPC”) Fair Trading Commission, Barbados (“FTC”)
Grand Bahama Power Company Limited (“GBPC”) The Grand Bahama Port Authority (“GBPA”)
Dominica Electricity Services Ltd. (“Domlec”) Independent Regulatory Commission, Dominica (“IRC”)
Peoples Gas System (“PGS”) – Gas Division of TEC FPSC
New Mexico Gas Company, Inc. (“NMGC”) New Mexico Public Regulation Commission (“NMPRC”)
SeaCoast Gas Transmission, LLC (“SeaCoast”) FPSC
Emera Brunswick Pipeline Company Limited (“Brunswick Pipeline”) Canadian Energy Regulator (“CER”)
Equity Investments  
NSP Maritime Link Inc. (“NSPML”) UARB
Labrador Island Link Limited Partnership (“LIL”) Newfoundland and Labrador Board of Commissioners of Public Utilities (“NLPUB”)
St. Lucia Electricity Services Limited (“Lucelec”) National Utility Regulatory Commission (“NURC”)
Maritimes & Northeast Pipeline Limited Partnership and Maritimes & Northeast Pipeline, LLC (“M&NP”) CER and FERC

  

On March 24, 2020, the Company completed the sale of Emera Maine. For further detail, refer to the “Significant Items Affecting Earnings” and “Developments” sections.

 

All amounts are in Canadian dollars (“CAD”), except for the Florida Electric Utility, Other Electric Utilities and Gas Utilities and Infrastructure sections of the MD&A, which are reported in US dollars (“USD”), unless otherwise stated.

 

Additional information related to Emera, including the Company’s Annual Information Form, can be found on SEDAR at www.sedar.com.

 

 

10 EMERA 2020 ANNUAL REPORT


 

MANAGEMENT’S DISCUSSION & ANALYSIS

 

FORWARD-LOOKING INFORMATION

 

This MD&A contains “forward-looking information” and statements which reflect the current view with respect to the Company’s expectations regarding future growth, results of operations, performance, carbon emissions reduction goals, business prospects and opportunities, and may not be appropriate for other purposes within the meaning of applicable Canadian securities laws. All such information and statements are made pursuant to safe harbour provisions contained in applicable securities legislation. The words “anticipates”, “believes”, “budget”, “could”, “estimates”, “expects”, “forecast”, “intends”, “may”, “might”, “plans”, “projects”, “schedule”, “should”, “targets”, “will”, “would” and similar expressions are often intended to identify forward-looking information, although not all forward-looking information contains these identifying words. The forward-looking information reflects management’s current beliefs and is based on information currently available to Emera’s management and should not be read as guarantees of future events, performance or results, and will not necessarily be accurate indications of whether, or the time at which, such events, performance or results will be achieved.

 

The forward-looking information is based on reasonable assumptions and is subject to risks, uncertainties and other factors that could cause actual results to differ materially from historical results or results anticipated by the forward-looking information. Factors that could cause results or events to differ from current expectations include without limitation: regulatory risk; operating and maintenance risks; changes in economic conditions; commodity price and availability risk; liquidity and capital market risk; future dividend growth; timing and costs associated with certain capital investment; the expected impacts on Emera of challenges in the global economy; estimated energy consumption rates; maintenance of adequate insurance coverage; changes in customer energy usage patterns; developments in technology that could reduce demand for electricity; global climate change; weather; unanticipated maintenance and other expenditures; system operating and maintenance risk; derivative financial instruments and hedging; interest rate risk; counterparty risk; disruption of fuel supply; country risks; environmental risks; foreign exchange; regulatory and government decisions, including changes to environmental, financial reporting and tax legislation; risks associated with pension plan performance and funding requirements; loss of service area; risk of failure of information technology infrastructure and cybersecurity risks; uncertainties associated with infectious diseases, pandemics and similar public health threats, such as the COVID-19 novel coronavirus (“COVID-19”) pandemic; market energy sales prices; labour relations; and availability of labour and management resources.

 

Readers are cautioned not to place undue reliance on forward-looking information, as actual results could differ materially from the plans, expectations, estimates or intentions and statements expressed in the forward-looking information. All forward-looking information in this MD&A is qualified in its entirety by the above cautionary statements and, except as required by law, Emera undertakes no obligation to revise or update any forward-looking information as a result of new information, future events or otherwise.

 

INTRODUCTION AND STRATEGIC OVERVIEW

 

Based in Halifax, Nova Scotia, Emera owns and operates cost-of-service rate-regulated electric and gas utilities in Canada, the United States and the Caribbean. Cost-of-service utilities provide essential gas and electric services in designated territories under franchises and are overseen by regulatory authorities. Emera’s strategic focus continues to be to safely deliver cleaner, affordable and reliable energy to its customers.

 

Emera’s investment in rate-regulated businesses is concentrated in Florida and Nova Scotia. These service areas have generally experienced stable regulatory policies and economic conditions. Emera’s portfolio of regulated utilities provides reliable earnings, cash flow and dividends. Earnings opportunities in regulated utilities are generally driven by the magnitude of net investment in the utility (known as “rate base”), and the amount of equity in the capital structure and the return on that equity (“ROE”) as approved through regulation. Earnings are also affected by sales volumes and operating expenses.

 

Emera’s $7.4 billion capital investment plan over the 2021-to-2023 period, and the potential for additional capital opportunities of $1.2 billion over the same period, results in a forecasted rate base growth of 7.5 per cent to 8.5 per cent through to 2023. The capital investment plan continues to include significant investments across the portfolio in renewable and cleaner generation, infrastructure modernization and customer-focused technologies. Emera’s capital investment plan is being funded primarily through internally generated cash flows and debt raised at the operating company level. Equity requirements in support of the Company’s capital investment plan will predominantly be funded in equity capital markets through the dividend reinvestment plan and issuance of common and preferred equity. Maintaining investment-grade credit ratings is a priority of management.

 

EMERA 2020 ANNUAL REPORT 11


 

MANAGEMENT’S DISCUSSION & ANALYSIS

 

Emera has provided annual dividend growth guidance of four to five per cent through to 2022. The Company targets a long- term dividend payout ratio of 70 to 75 per cent, and while the payout ratio is likely to exceed that target through and beyond the forecast period, it is expected to return to that range over time.

 

Seasonal patterns and other weather events affect demand and operating costs. Similarly, mark-to-market adjustments and foreign currency exchange can have a material impact on financial results for a specific period. Emera’s consolidated net income and cash flows are impacted by movements in the US dollar relative to the Canadian dollar and benefit from a weaker Canadian dollar. Emera may hedge both transactional and translational exposure. These impacts, as well as the timing of capital investments and other factors, mean that results in any one quarter are not necessarily indicative of results in any other quarter or for the year as a whole.

 

Energy markets worldwide are facing significant change and Emera is well positioned to respond to shifting customer demands, digitization, decarbonization, complex regulatory environments and decentralized generation.

 

Customers are looking for more choice, better control, and enhanced reliability in a time where costs of decentralized generation and storage have become more competitive in some regions. Advancing technologies are transforming the way utilities interact with their customers and generate and transmit energy. In addition, climate change and extreme weather are shaping how utilities operate and how they invest in infrastructure. There is also an overall need to replace aging infrastructure and further enhance reliability. Emera sees opportunity in all these trends. Emera’s strategy is to fund investments in renewable energy and technology assets which protect the environment and benefit customers through fuel or operating cost savings.

 

For example, significant investments to facilitate the use of renewable and low-carbon energy include the Maritime Link in Atlantic Canada, the ongoing construction of solar generation at Tampa Electric, and the modernization of the Big Bend Power Station at Tampa Electric. Emera’s utilities are also investing in reliability projects and replacing aging infrastructure. All of these projects demonstrate Emera’s strategy of safely delivering cleaner, reliable, and affordable energy for its customers.

 

Building on its decarbonization progress over the past 15 years, Emera is continuing its efforts by establishing clear carbon reduction goals and a vision to achieve net-zero carbon emissions by 2050.

 

This vision is inspired by Emera’s strong track record, the Company’s experienced team, and a clear path to Emera’s interim carbon goals. With existing technologies and resources and the benefit of supportive regulatory decisions, Emera plans and expects to achieve the following goals compared to corresponding 2005 levels:

 

A 55 per cent reduction in carbon emissions by 2025.
An 80 per cent reduction in coal usage by 2023 and the retirement of Emera’s last existing coal unit no later than 2040.
At least an 80 per cent reduction in carbon emissions by 2040.

 

Emera seeks to achieve these goals and realize its net-zero vision while remaining focused on maintaining affordability, enhancing reliability, adopting emerging technologies and working constructively with policymakers, regulators, partners, investors, and Emera’s communities.

 

Emera is committed to world-class safety, operational excellence, good governance, excellent customer service, reliability, being an employer of choice, and building constructive relationships.

 

12 EMERA 2020 ANNUAL REPORT


 

MANAGEMENT’S DISCUSSION & ANALYSIS

 

NON-GAAP FINANCIAL MEASURES

 

Emera uses financial measures that do not have standardized meaning under USGAAP and may not be comparable to similar measures presented by other entities. Emera calculates the non-GAAP measures by adjusting certain GAAP measures for specific items the Company believes are significant, but not reflective of underlying operations in the period. These measures are discussed and reconciled below.

 

Adjusted Net Income

 

Emera calculates an adjusted net income measure by excluding the effect of mark-to-market (“MTM”) adjustments, the gain on the sale of Emera Maine in 2020 and impairment charges.

 

The MTM adjustments are a result of the following:

 

the MTM adjustments related to Emera’s held-for-trading (“HFT”) commodity derivative instruments, including adjustments related to the price differential between the point where natural gas is sourced and where it is delivered;
the MTM adjustments included in Emera’s equity income related to the business activities of Bear Swamp Power Company LLC (“Bear Swamp”);
the amortization of transportation capacity recognized as a result of certain Emera Energy marketing and trading transactions;
the MTM adjustments related to an interest rate swap in Brunswick Pipeline;
the MTM adjustments related to equity securities held in BLPC and Emera Reinsurance, a captive reinsurance company in the Other segment; and
the MTM adjustments related to Emera’s foreign exchange cash flow hedges entered to manage foreign exchange earnings exposure.

 

Management believes excluding from net income the effect of these MTM valuations and changes thereto, until settlement, better aligns the intent and financial effect of these contracts with the underlying cash flows and ongoing operations of the business, and allows investors to better understand and evaluate the business. Management and the Board of Directors exclude these MTM adjustments for evaluation of performance and incentive compensation. For further detail on MTM adjustments, refer to the “Consolidated Financial Review” section and the “Financial Highlights” sections for Other Electric Utilities and Other segments.

 

In 2020, the Company recognized a gain on the sale of Emera Maine. Management believes excluding this from net income better distinguishes ongoing operations of the business and allows investors to better understand and evaluate the business. Refer to the “Significant Items Affecting Earnings” and “Developments” sections for further detail related to the sale of Emera Maine. While the gain on sale has been excluded from adjusted earnings, earnings for the Other Electric Utilities segment only includes earnings from Emera Maine up to the date of its sale in Q1 2020.

 

In 2019 and 2020, the Company recognized certain non-cash impairment charges. Management believes excluding from net income the effect of these charges better distinguishes ongoing operations of the business and allows investors to better understand and evaluate the Company. For further details, refer to the “Significant Items Affecting Earnings”, “Financial Highlights – Other Electric Utilities” and “Financial Highlights – Other” sections.

 

The following reconciles reported net income attributable to common shareholders to adjusted net income attributable to common shareholders; and reported earnings per common share – basic, to adjusted earnings per common share – basic:

 

For the
millions of Canadian dollars (except per share amounts)
  Three months ended
December 31
      Year ended
December 31
 
    2020   2019   2020   2019   2018  
Net income attributable to common shareholders   $ 273   $ 193   $ 938   $ 663   $ 710  
Gain on sale, net of tax and transaction costs   $   $   $ 309   $   $  
Impairment charges, net of tax   $   $ (34 ) $ (26 ) $ (34 ) $  
After-tax MTM gains (losses)   $ 85   $ 82   $ (10 ) $ 76   $ 39  
Adjusted net income attributable to common shareholders   $ 188   $ 145   $ 665   $ 621   $ 671  
Earnings per common share – basic   $ 1.09   $ 0.79   $ 3.78   $ 2.76   $ 3.05  
Adjusted earnings per common share – basic   $ 0.75   $ 0.60   $ 2.68   $ 2.59   $ 2.88  

 

EMERA 2020 ANNUAL REPORT 13


 

MANAGEMENT’S DISCUSSION & ANALYSIS

 

EBITDA and Adjusted EBITDA

 

Earnings before interest, income taxes, depreciation and amortization (“EBITDA”) is a non-GAAP financial measure used by Emera. EBITDA is used by numerous investors and lenders to better understand cash flows and credit quality. EBITDA is useful to assess Emera’s operating performance and indicates the Company’s ability to service or incur debt, invest in capital and finance working capital requirements.

 

Adjusted EBITDA is a non-GAAP financial measure used by Emera. Similar to adjusted net income calculations described above, this measure represents EBITDA absent the income effect of Emera’s MTM, the gain on sale of Emera Maine and impairment charges, as discussed above.

 

The Company’s EBITDA and Adjusted EBITDA may not be comparable to the EBITDA measures of other companies but, in management’s view, appropriately reflect Emera’s specific operating performance. These measures are not intended to replace “Net income attributable to common shareholders” which, as determined in accordance with GAAP, is an indicator of operating performance.

 

The following is a reconciliation of reported net income to EBITDA and Adjusted EBITDA:

 

For the
millions of Canadian dollars
  Three months ended
December 31
      Year ended
December 31
 
    2020   2019   2020   2019   2018  
Net income (1)   $ 284   $ 192   $ 984   $ 710   $ 747  
Interest expense, net     159     181     679     738     713  
Income tax expense     57     43     341     61     69  
Depreciation and amortization     217     225     881     903     916  
EBITDA     717     641     2,885     2,412     2,445  
Gain on sale (excluding transaction costs)             585          
Impairment charges         (34 )   (25 )   (34 )    
MTM gains (losses), excluding income tax and interest     118     118     (18 )   107     58  
Adjusted EBITDA   $ 599   $ 557   $ 2,343   $ 2,339   $ 2,387  

  

(1) Net income is income before Non-controlling interest in subsidiaries and Preferred stock dividends.

 

14 EMERA 2020 ANNUAL REPORT


 

MANAGEMENT’S DISCUSSION & ANALYSIS

 

CONSOLIDATED FINANCIAL REVIEW

 

SIGNIFICANT ITEMS AFFECTING EARNINGS

 

2020

 

TECO Guatemala Holdings (“TGH”) International Arbitration and Award 

On November 24, 2020, a payment was made by the Republic of Guatemala related to an investment TGH, a wholly owned subsidiary of TECO Energy, indirectly held prior to acquisition by Emera. The payment was based on an award issued by an International Centre for the Settlement of Investment Disputes (“ICSID”) tribunal in 2013. The payment of $49 million ($36 million after tax or $0.15 per common share), net of legal costs was recognized in “Other Income” on the Consolidated Statements of Income. For further detail, refer to note 27 in the consolidated financial statements.

 

Gain on Sale of Emera Maine and Impairment Charges
On March 24, 2020, Emera completed the sale of Emera Maine for a total enterprise value of $2.0 billion ($1.4 billion USD). A gain on sale of $585 million ($309 million after tax, or $1.26 per common share), net of transaction costs, was recognized in “Other Income” on the Consolidated Statements of Income. For further detail, refer to the “Developments” section.

 

As a result of the sale, earnings contribution from Emera Maine was $9 million lower in Q4 2020 than in Q4 2019 and $41 million lower for the year ended December 31, 2020.

 

In addition, impairment charges of $25 million ($26 million after tax) for the year ended December 31, 2020 were recognized on certain other assets.

 

Earnings Impact of After-Tax MTM Gains and Losses
After-tax MTM gains increased $3 million to $85 million in Q4 2020, compared to $82 million in Q4 2019. For the year ended December 31, 2020, after-tax MTM losses were $86 million more than the $76 million gain recorded in 2019. This increase was due to higher amortization of gas transportation assets in 2020, changes in existing positions and a larger reversal of MTM losses in 2019 at Emera Energy. This was partially offset by gains on foreign exchange cash flow hedges.

 

Earnings Impact of Q1 2019 Sale of NEGG and Bayside Facilities
Earnings contribution from Emera Energy Generation was $21 million lower for the year ended December 31, 2020 compared to 2019 due to the March 2019 sale of the New England Gas Generating (“NEGG”) and Bayside generation facilities.

 

2019

 

GBPC Hurricane Dorian Restoration
In Q3 2019, Hurricane Dorian struck Grand Bahama as a Category 5 hurricane, causing significant damage across the island. Emera’s 2019 earnings decreased by approximately $62 million ($0.26 per common share), as a result of the impact of the hurricane.

 

In Q4 2019, Emera recognized impairment charges of $34 million, including $30 million related to GBPC’s goodwill due to a decrease in expected future cash flows resulting from the impacts of Hurricane Dorian storm recovery and changes in the anticipated long term regulated capital structure of GBPC. This non-cash charge was recorded in “Impairment charges” in the Consolidated Statements of Income. For further information, refer to note 22 to the consolidated financial statements.

 

GBPC’s 2019 earnings decreased $13 million ($0.05 per common share) compared to 2018 due to reduced load as a result of the storm. Emera recorded a corporate loss of $15 million ($0.06 per common share) in 2019, in the Other segment, for the corporate share of the unrecoverable loss on GBPC facilities.

 

EMERA 2020 ANNUAL REPORT 15


 

MANAGEMENT’S DISCUSSION & ANALYSIS

 

CONSOLIDATED FINANCIAL HIGHLIGHTS BY BUSINESS SEGMENT

 

For the
millions of Canadian dollars
  Three months ended
December 31
    Year ended
December 31
 
Adjusted Net Income     2020     2019     2020     2019     2018  
Florida Electric Utility   $ 101   $ 80   $ 501   $ 419   $ 381  
Canadian Electric Utilities     57     58     221     229     218  
Other Electric Utilities     8     14     33     76     89  
Gas Utilities and Infrastructure     45     51     162     183     136  
Other     (23 )   (58 )   (252 )   (286 )   (153 )
Adjusted net income attributable to common shareholders   $ 188   $ 145   $ 665   $ 621   $ 671  
Gain on sale, net of tax and transaction costs             309          
Impairment charges, net of tax         (34 )   (26 )   (34 )    
After-tax MTM gains (losses)     85     82     (10 )   76     39  
Net income attributable to common shareholders   $ 273   $ 193   $ 938   $ 663   $ 710  

 

The following table highlights the significant changes in adjusted net income from 2019 to 2020:

 

For the
millions of Canadian dollars
  Three months ended
December 31
  Year ended
December 31
 
Adjusted net income – 2019   $ 145   $ 621  
Operating Unit Performance:              
Increased earnings at Tampa Electric in both periods due to the in-service of solar generation, higher allowance for funds used during construction (“AFUDC”) earnings from the Big Bend modernization and solar projects, increased load driven by warmer weather, increased mix of residential sales related to the impact of COVID-19, customer growth, and a credit to depreciation expense as a result of a regulatory settlement     21     82  
Increased earnings contribution from the Caribbean utilities in Q4 2020 due to continued recovery from Hurricane Dorian at GBPC. Year-over-year, earnings contribution decreased in 2020 due to lower sales related to the impact of COVID-19 and continued recovery from Hurricane Dorian at GBPC     3     (12)  
Decreased earnings at NSPI year-over-year due to higher income tax expense, decreased sales volumes due to warmer weather, and lower commercial sales related to the impact of COVID-19. The decrease was partially offset by decreased operating, maintenance and general (“OM&G”) expense and increased mix of residential sales related to COVID-19     1     (12)  
Decreased earnings due to the sale of Emera Maine in Q1 2020 and the sale of Emera Energy’s NEGG and Bayside generation facilities in Q1 2019     (8)     (62)  
Tax Related:              
Recognition of corporate income tax recovery deferred as a regulatory liability in 2018 at BLPC         10  
Revaluation of Corporate, NSPI and Emera Energy net deferred income tax assets and liabilities due to the Q1 2020 reduction in the Nova Scotia provincial corporate income tax rate         (14)  
Q3 2019 recognition of tax benefits related to change in treatment of net operating loss(“NOL”) carryforwards and tax reform benefits recognized in Q2 2019 in NMGC         (19)  
Corporate:              
TGH award, net of tax and legal costs. Refer to the “Significant Items Affecting Earnings” section and note 27 of the consolidated financial statements     36     36  
Decreased interest expense in the Other segment primarily due to lower interest rates and repayment of corporate long-term debt     10     30  
2019 recognition of corporate loss for the share of the unrecoverable loss on GBPC’s facilities related to Hurricane Dorian     6     15  
Timing of Q4 preferred share dividend declaration     (11 )    
Other Variances:     (15 )   (10 )
Adjusted net income – 2020   $ 188   $ 665  

 

Refer to the “Financial Highlights” section for further detail of reportable segment contributions.

 

16 EMERA 2020 ANNUAL REPORT


 

MANAGEMENT’S DISCUSSION & ANALYSIS

 

For the
millions of Canadian dollars
  Year ended
December 31
 
      2020     2019     2018  
Operating cash flow before changes in working capital   $ 1,420   $ 1,598   $ 1,806  
Change in working capital     217     (73 )   (116 )
Operating cash flow   $ 1,637   $ 1,525   $ 1,690  
Investing cash flow   $ (1,224 ) $ (1,617 ) $ (2,190 )
Financing cash flow   $ (372 ) $ 14   $ 344  

  

As at
millions of Canadian dollars
  December 31  
      2020     2019     2018  
Total assets   $ 31,234   $ 31,842   $ 32,314  
Total long-term debt (including current portion)   $ 13,721   $ 14,180   $ 15,411  

 

Refer to the “Consolidated Cash Flow Highlights” section for further discussion of cash flow.

 

CONSOLIDATED INCOME STATEMENT HIGHLIGHTS

 

For the
millions of Canadian dollars
(except per share amounts)
  Three months ended
December 31
  Variance   Year ended
December 31
  Variance   Year ended
December 31
 
    2020   2019       2020   2019     2018  
Operating revenues   $ 1,537   $ 1,616   $ (79 ) $ 5,506   $ 6,111   $ (605 ) $ 6,524  
Operating expenses     1,148     1,237     89     4,359     4,768     409     5,126  
Income from operations     389     379     10     1,147     1,343     (196 )   1,398  
Income from equity investments     36     36         149     154     (5 )   154  
Other income (expenses), net     75     1     74     708     12     696     (23 )
Interest expense, net     159     181     22     679     738     59     713  
Income tax expense     57     43     (14 )   341     61     (280 )   69  
Net income     284     192     92     984     710     274     747  
Net income attributable to common shareholders     273     193     80     938     663     275     710  
Gain on sale, net of tax and transaction costs                 309         309      
Impairment charges, net of tax         (34 )   34     (26 )   (34 )   8      
After-tax MTM gains (losses)     85     82     3     (10 )   76     (86 )   39  
Adjusted net income attributable to common shareholders   $ 188   $ 145   $ 43   $ 665   $ 621   $ 44   $ 671  
Earnings per common share – basic   $ 1.09   $ 0.79   $ 0.30   $ 3.78   $ 2.76   $ 1.02   $ 3.05  
Earnings per common share – diluted   $ 1.08   $ 0.80   $ 0.28   $ 3.78   $ 2.76   $ 1.02   $ 3.04  
Adjusted earnings per common share – basic   $ 0.75   $ 0.60   $ 0.15   $ 2.68   $ 2.59   $ 0.09   $ 2.88  
Dividends per common share declared   $ 0.6375   $   $ 0.6375   $ 2.4750   $ 2.3750   $ 0.1000   $ 2.2825  
Adjusted EBITDA   $ 599   $ 557   $ 42   $ 2,343   $ 2,339   $ 4   $ 2,387  

 

EMERA 2020 ANNUAL REPORT 17


 

MANAGEMENT’S DISCUSSION & ANALYSIS

 

Operating Revenues

 

For the fourth quarter of 2020, operating revenues decreased $79 million compared to the fourth quarter in 2019. Absent decreased MTM gains of $10 million, operating revenues decreased $69 million due to:

 

$64 million decrease in the Other Electric Utilities segment due to the sale of Emera Maine in Q1 2020;

$18 million decrease in the Other Electric Utilities segment due to lower fuel revenues as a result of lower fuel prices at BLPC; and

$13 million decrease in the Florida Electric Utility segment due lower clause revenues as a result of a decrease in fuel costs, partially offset by the in-service of solar generation projects, colder weather than the prior quarter, a greater mix of residential sales related to COVID-19, and customer growth.

 

These impacts were partially offset by:

 

$13 million increase at NSPI in the Canadian Electric Utilities segment due to higher Maritime Link assessment revenue compared to 2019 and increased residential sales volumes primarily due to the impact of the COVID-19 pandemic, increased industrial sales volumes, and increased fuel-related pricing. This was partially offset by decreased sales volumes due to warmer weather than the prior year and lower commercial sales volumes related to the impact of the COVID-19 pandemic.

 

For the year ended December 31, 2020, operating revenues decreased $605 million compared to 2019. Absent increased MTM losses of $148 million, operating revenues decreased by $457 million due to:

 

$211 million decrease in the Other Electric Utilities segment due to the sale of Emera Maine in Q1 2020;

$127 million decrease in the Florida Electric Utility segment due to lower clause-related revenue as a result of a decrease in fuel costs, partially offset by the in-service of solar generation projects, a greater mix of residential sales related to the impact of COVID-19, warmer weather than the prior year, and customer growth;

$109 million decrease in the Other segment due to the sale of NEGG and Bayside in Q1 2019;

$61 million decrease in the Gas Utilities and Infrastructure segment as a result of lower clause-related revenue at PGS, lower off-system sales at PGS, warmer weather than the prior year at NMGC, NMGC’s recognition of tax reform benefits in 2019 and lower commercial sales at PGS related to the COVID-19 pandemic. This was partially offset by customer growth at PGS; and

$59 million decrease in the Other Electric Utilities segment due lower fuel revenue as a result of lower fuel prices at BLPC, the impact of the COVID-19 pandemic at GBPC and BLPC, and the impact of Hurricane Dorian at GBPC.

 

These impacts were partially offset by:

 

$64 million increase at NSPI in the Canadian Electric Utilities segment, due to higher Maritime Link assessment revenue compared to 2019, increased fuel related pricing, and higher mix of residential sales volumes, partially offset by warmer weather than prior year and decreased commercial sales volumes related to the impact of the COVID-19 pandemic.

 

Operating Expenses

 

For the fourth quarter of 2020, operating expenses decreased $89 million compared to the fourth quarter of 2019. Absent the $34 million impairment charge in Q4 2019 and decreased MTM losses of $1 million, operating expenses decreased by $54 million due to:

 

$49 million decrease in the Other Electric Utilities segment due to the sale of Emera Maine in Q1 2020; and

$25 million decrease in the Florida Electric Utility segment due to lower natural gas prices.

 

These impacts were partially offset by:

 

$11 million increase at NSPI in the Canadian Electric Utilities segment mainly due to higher Maritime Link assessment costs in 2020, partially offset by decreased OM&G expenses and changes in regulatory deferrals; and

$10 million increase in the Gas Utilities and Infrastructure segment due to higher commodity costs at PGS and NMGC.

 

18 EMERA 2020 ANNUAL REPORT


 

MANAGEMENT’S DISCUSSION & ANALYSIS

 

For the year ended December 31, 2020, operating expenses decreased $409 million compared to 2019. Absent the decreased impairment charges of $8 million and increased MTM gains of $5 million, operating expenses decreased $396 million due to:

 

$196 million decrease in the Florida Electric Utility segment due to lower natural gas prices;

$148 million decrease in the Other Electric Utilities segment, primarily due to the sale of Emera Maine in Q1 2020;

$80 million decrease in the Other segment as a result of the sale of NEGG and Bayside facilities in Q1 2019;

$41 million decrease in the Gas Utilities and Infrastructure segment due to lower commodity costs and lower system supply to customers at PGS and NMGC and lower volume of off-system sales at PGS; and

$41 million decrease in the Other Electric segment due to lower oil prices at BLPC.

 

These impacts were partially offset by:

 

$61 million increase at NSPI in the Canadian Electric Utilities segment, primarily due to changes in regulatory deferrals, and higher Maritime Links assessments costs in 2020 partially offset by decreased OM&G expenses.

 

Other Income (Expenses), Net 

The increase in other income (expenses), net for the fourth quarter in 2020 was primarily due to the TGH award, the corporate share of unrecoverable loss at GBPC facilities in 2019 related to Hurricane Dorian and increased AFUDC equity earnings in 2020 primarily related to the Big Bend modernization and solar projects at Tampa Electric. For the year ended December 31, 2020, the increase was also due to the pre-tax gain on the sale of Emera Maine.

 

Interest Expense 

Interest expense, net was lower for Q4 2020 and year ended December 31, 2020 compared to 2019 due to lower interest rates and the repayment of corporate debt.

 

Income Tax Expense 

The increase in income tax expense for Q4 2020 compared to the same period in 2019, was primarily due to increased income before provision for income taxes. The increase in income tax expense in 2020, compared to 2019, was primarily due to the gain on the sale of Emera Maine.

 

Net Income and Adjusted Net Income Attributable to Common Shareholders 

For the fourth quarter of 2020, net income attributable to common shareholders was favourably impacted by the $3 million increase in after-tax MTM gains and the 2019 impairment charge of $34 million. Absent favourable MTM changes and the impairment charges, adjusted net income attributable to common shareholders increased $43 million. The increase was due to increased contributions from Florida Electric Utility, the TGH award, decreased corporate interest costs and the 2019 corporate share of unrecoverable loss at GBPC related to Hurricane Dorian. These were partially offset by the timing of preferred share dividends and lower earnings contribution from Emera Maine as a result of its sale.

 

For the year ended December 31, 2020, net income attributable to common shareholders was favourably impacted by the $309 million after-tax gain on the sale of Emera Maine and the impairment charges, and unfavourably impacted by the $86 million increase in after-tax MTM losses, primarily related to Emera Energy. Absent the net gain on sale of Emera Maine, impairment charges, and the unfavourable MTM changes, adjusted net income attributable to common shareholders increased $44 million. The increase was due to higher earnings contribution from Florida Electric Utility, the TGH award, lower corporate interest costs and the 2019 corporate share of unrecoverable loss at GBPC related to Hurricane Dorian. These were partially offset by lower earnings at Emera Maine as a result of its sale in Q1 2020, reduced earnings at NEGG and Bayside facilities as a result of their sale in Q1 2019, lower earnings contribution from NSPI and the Caribbean utilities, revaluation of deferred taxes due to a reduction in the Nova Scotia corporate income tax rate, and the 2019 recognition of tax reform benefits in NMGC.

 

Earnings and Adjusted Earnings per Common Share – Basic 

Earnings per common share – basic and adjusted earnings per common share – basic were higher for the fourth quarter and the year ended December 31, 2020 due to increased earnings as discussed above.

 

EMERA 2020 ANNUAL REPORT 19


 

MANAGEMENT’S DISCUSSION & ANALYSIS

 

Effect of Foreign Currency Translation

 

Emera operates internationally, including in Canada, the US and various Caribbean countries. As such, the Company generates revenues and incurs expenses denominated in local currencies which are translated into CAD for financial reporting. Changes in translation rates, particularly in the value of the USD against the CAD, can positively or adversely affect results.

 

Earnings from Emera’s foreign operations are translated into CAD. In general, Emera’s earnings benefit from a weakening CAD and are adversely impacted by a strengthening CAD. The impact of foreign exchange in any period is driven by rate changes, the timing of earnings from foreign operations during the period, the percentage of earnings from foreign operations in the period and the impact of foreign exchange cash flow hedges entered to manage foreign exchange earnings exposure.

 

Results of foreign operations are translated at the weighted average rate of exchange and assets and liabilities of foreign operations are translated at period-end rates. The relevant CAD/USD exchange rates for 2020 and 2019 are as follows:

 

    Three months ended
December 31
  Year ended
December 31
 
      2020     2019     2020     2019  
Weighted average CAD/USD   $ 1.30   $ 1.32   $ 1.34   $ 1.33  
Period end CAD/USD exchange rate   $ 1.27   $ 1.30   $ 1.27   $ 1.30  

 

Strengthening of the CAD exchange rates increased earnings by $1 million and decreased adjusted earnings by $1 million in Q4 2020 compared to Q4 2019. The weakening of the CAD exchange rates increased earnings by $19 million and adjusted earnings by $5 million in 2020, compared to 2019.

 

Consistent with the Company’s risk management policies, Emera partially manages currency risks through matching US denominated debt to finance its US operations and uses foreign currency derivative instruments to hedge specific transactions and earnings exposure. Emera does not utilize derivative financial instruments for foreign currency trading or speculative purposes.

 

The table below includes Emera’s significant segments whose contributions to adjusted earnings are recorded in USD currency.

 

millions of US dollars   Three months ended
December 31
  Year ended
December 31
 
      2020     2019     2020     2019  
Florida Electric Utility   $ 76   $ 61   $ 372   $ 316  
Other Electric Utilities     5     10     24     57  
Gas Utilities and Infrastructure (1)     30     33     97     115  
      111     104     493     488  
Other segment (2)     5     (28 )   (102 )   (159 )
Total (3)   $ 116   $ 76   $ 391   $ 329  

(1) Includes USD net income from PGS, NMGC, SeaCoast and M&NP.

(2) Includes Emera Energy’s USD adjusted net income from Emera Energy Services, Bear Swamp and interest expense on Emera’s USD denominated debt and in 2019, net income from NEGG.

(3) Amounts above do not include the impact of MTM.

 

BUSINESS OVERVIEW AND OUTLOOK

 

COVID-19 PANDEMIC

 

During the year ended December 31, 2020, the ongoing COVID-19 pandemic has affected all service territories in which Emera operates. Emera’s utilities provide essential services and continue to operate to meet customer demand. The Company’s priorities continue to be the reliable delivery of essential energy services while maintaining the health and safety of its customers and employees and supporting the communities Emera operates in.

 

The pandemic has generally resulted in lower load and higher operating costs than what otherwise would have been experienced at the Company’s utilities. Some of Emera’s utilities have been impacted more than others. However, on a consolidated basis these unfavourable impacts have not had a material financial impact to net earnings primarily due to a change in the mix of sales across customer classes. Lower commercial and industrial sales have been partially offset by increased sales to residential customers, which have a higher contribution to fixed cost recovery. Favourable weather in 2020, particularly in Florida, has further reduced the consolidated impact. The Company has not deferred any costs for future recovery as a result of the pandemic. Capital project delays and supply chain disruptions have also been minimal to date. Management continues to closely monitor developments related to COVID-19.

 

20 EMERA 2020 ANNUAL REPORT


 

MANAGEMENT’S DISCUSSION & ANALYSIS

 

Governments world-wide have implemented measures intended to address the pandemic. These measures include travel and transportation restrictions, quarantines, physical distancing, closures of commercial and industrial facilities, shutdowns, shelter- in-place orders and other health measures. These measures are adversely impacting global, national and local economies. Global equity markets have experienced significant volatility and governments and central banks are implementing measures designed to stabilize economic conditions. The pace and strength of economic recovery is uncertain and may vary among jurisdictions.

 

In March 2020, Emera activated its company-wide pandemic and business continuity plans, including travel restrictions, directing employees to work remotely whenever possible, restricting access to operating facilities, physical distancing and implementing additional protocols (including the expanded use of personal protective equipment) for work within customers’ premises. In jurisdictions where it is safe to do so, some parts of the business have commenced a workplace re-entry strategy. The Company is monitoring recommendations by local and national public health authorities related to COVID-19 and is adjusting operational requirements as needed.

 

Emera’s utilities are working with customers on relief initiatives in response to the effect of the pandemic on customers’ ability to pay and their need for continued service. These initiatives have included the temporary suspension of disconnection for non-payment of bills and the development of payment arrangements where necessary. In Q3 2020, most of Emera’s utilities resumed disconnection processes for non-payment. As a result of the temporary suspension of disconnections, the Company’s utilities experienced an increase in the aging of customer receivables. This trend has begun to reverse as normal disconnection processes resume. There have been no significant customer defaults as a result of bankruptcies with many accounts being secured by deposits. As of December 31, 2020, adjustments to the allowance for credit losses have increased but have not had a material impact on earnings. The full impact of potential credit losses due to customer non-payment is not known at this time. The utilities are continuing to monitor customer accounts and are working with customers on payment arrangements.

 

The extent of the future impact of COVID-19 on the Company’s financial results and business operations cannot be predicted at this time and will depend on future developments, including the duration and severity of the pandemic, timing and effectiveness of vaccinations, further potential government actions and future economic activity and energy usage. In Q1 2020, the Company updated its principal risks to reflect this uncertainty. For this risk update, refer to the “Risk Management and Financial Instruments” section of this document and note 27 in the consolidated financial statements. The Company has disclosed the impact of this uncertainty on its accounting estimates used in the preparation of the financial statements. For further detail, refer to the “Critical Accounting Estimates” section of this document, and the “Use of Management Estimates” section of note 1 in the consolidated financial statements.

 

Potential future impacts of COVID-19 on the business may include the following:

 

Lower earnings as a result of lower sales volumes due to continued economic slowdowns and the pace and strength of economic recovery;

Delays of capital projects as a result of construction shutdowns, government restrictions on non-essential capital work, travel restrictions for contractors or supply chain disruptions;

Deferral of and adjustment to regulatory filings, hearings, decisions and recovery periods; and

Decreased cash flow from operations due to lower earnings and slower collection of accounts receivable or increased credit losses.

 

To date, the above have not had a material financial impact on the Company. Future impacts on the business will depend on future developments, including the duration and severity of the pandemic and the pace and strength of the economic recovery.

 

Refer to the outlook sections below, by segment, for affiliate specific impacts. These segment outlooks are based on the information currently available, however, the total impact of COVID-19 is unknown at this time.

 

Depending on the duration of the COVID-19 pandemic, the forecasted capital expenditures disclosed below may be delayed due to supply chain disruptions, travel restrictions for contractors or the deferral of non-essential capital work. The Company currently expects to continue to have adequate liquidity given its cash position, existing bank facilities, and access to capital, but will continue to monitor the impact of COVID-19 on future cash flows. For further detail, refer to the “Liquidity and Capital Resources” section of this document.

 

EMERA 2020 ANNUAL REPORT 21


 

MANAGEMENT’S DISCUSSION & ANALYSIS

 

FLORIDA ELECTRIC UTILITY 

 

Florida Electric Utility consists of Tampa Electric, a vertically integrated regulated electric utility engaged in the generation, transmission and distribution of electricity, serving customers in West Central Florida. Tampa Electric has approximately $10 billion USD of assets and approximately 792,500 customers at December 31, 2020. Tampa Electric owns 5,790 MW of generating capacity, of which 78 per cent is natural gas-fired, 12 per cent is coal and 10 per cent is solar. Tampa Electric owns 2,165 kilometres of transmission facilities and 19,250 kilometres of distribution facilities.

 

Tampa Electric’s approved regulated ROE range is 9.25 per cent to 11.25 per cent, based on an allowed equity capital structure of 54 per cent. An ROE of 10.25 per cent is used for the calculation of the return on investments for clauses.

 

Due to continued growth in rate base, Tampa Electric anticipates earning near or below the bottom of the allowed ROE range in 2021. Tampa Electric sales volumes are expected to be lower than in 2020, which benefited from weather that was warmer than in recent years. As a result, Tampa Electric anticipates earnings to be slightly lower than in 2020. Tampa Electric expects customer growth rates in 2021 to be consistent with 2020, reflective of current expected economic growth in Florida.

 

On February 1, 2021, Tampa Electric notified the FPSC of its intent to seek a base rate increase, reflecting incremental revenue requirements of approximately $280 million USD to $295 million USD, effective January 2022. Tampa Electric’s proposed rates include recovery for the costs of the first phase of the Big Bend modernization project, 225 MW of utility-scale solar projects, the advanced metering infrastructure (“AMI”) investment, and accelerated recovery of the remaining net book value of retiring assets. Tampa Electric also intends to seek approval for Generation Base Rate Adjustments of $130 million USD to recover the costs of the second phase of the Big Bend modernization project and additional utility-scale solar projects in subsequent years. These filing amounts are estimates until Tampa Electric completes and files its detailed case. Tampa Electric expects to file its detailed case on or after April 2, 2021, and a decision by the FPSC is expected by the end of 2021.

 

On October 3, 2019, the FPSC issued a rule to implement a Storm Protection Plan (“SPP”) Cost Recovery Clause. This new clause provides a process for Florida investor-owned utilities, including Tampa Electric, to recover transmission and distribution storm hardening costs for incremental activities not already included in base rates. Tampa Electric submitted its storm protection plan with the FPSC on April 10, 2020. On April 27, 2020, Tampa Electric submitted a settlement agreement with the FPSC which specified a $15 million USD base rate reduction for SPP program costs previously recovered in base rates beginning January 1, 2021. On June 9, 2020, the FPSC approved this settlement agreement. On August 3, 2020, Tampa Electric submitted another settlement agreement to the FPSC for approval, including cost recovery of approximately $39 million USD in proposed storm protection project costs for 2020 and 2021. This cost recovery includes the $15 million USD of costs removed from base rates. This settlement agreement was approved on August 10, 2020 and Tampa Electric’s cost recovery began in January 2021. The current approved plan will apply for the years 2020, 2021 and 2022, and Tampa Electric will file a new plan in 2022 to determine cost recovery in 2023, 2024, and 2025.

 

On February 18, 2020, Tampa Electric announced its intention to invest approximately $800 million USD in an additional 600 MW of new utility-scale solar photovoltaic projects by the end of 2023. As of December 31, 2020, Tampa Electric has invested approximately $213 million USD in these projects. AFUDC is being earned on these projects during construction. For further detail, refer to the “Developments” section.

 

Tampa Electric expects to invest approximately $850 million USD through 2023 to modernize the Big Bend Power Station, of which approximately $526 million USD has been invested through December 31, 2020. The modernization project will repower Big Bend Unit 1 with natural gas combined-cycle technology and eliminate coal as this unit’s fuel. On June 1, 2020, Tampa Electric retired the Unit 1 components that will not be used in the modernized plant. In addition, Tampa Electric plans to retire Big Bend Unit 2 in 2021. In accordance with Tampa Electric’s 2017 settlement agreement, Tampa Electric was not required to request an asset recovery schedule for retired assets until the next depreciation study. On December 30, 2020, Tampa Electric filed a depreciation and dismantlement study and request for capital recovery schedules with the FPSC.

 

Tampa Electric plans to retire Big Bend Unit 3 in 2023 as it is in the best interest of customers from economic, environmental risk and operational perspectives. Similar to the retirement plan for Unit 1 and Unit 2, Tampa Electric will continue to account for its existing investment in Unit 3 in electric utility plant and depreciate the assets using the current depreciation rates until the FPSC approves Tampa Electric’s next depreciation and dismantlement study.

 

In 2021, capital investment in the Florida Electric Utility segment is expected to be approximately $1.2 billion USD (2020 – $1.0 billion USD), including AFUDC. Capital projects include solar investments, continuation of the modernization of the Big Bend Power Station, storm hardening investments and AMI.

 

22 EMERA 2020 ANNUAL REPORT


 

MANAGEMENT’S DISCUSSION & ANALYSIS

 

CANADIAN ELECTRIC UTILITIES

 

Canadian Electric Utilities includes NSPI and ENL. NSPI is a vertically integrated regulated electric utility engaged in the generation, transmission and distribution of electricity and the primary electricity supplier to customers in Nova Scotia. ENL is a holding company with equity investments in NSPML and LIL: two transmission investments related to the development of an 824 MW hydroelectric generating facility at Muskrat Falls on the Lower Churchill River in Labrador.

 

NSPI

 

With approximately $5.5 billion of assets and approximately 529,000 customers, NSPI owns 2,433 MW of generating capacity, of which approximately 43 per cent is coal-fired; 28 per cent is natural gas and/or oil; 20 per cent is hydro and wind; 7 per cent is petcoke and 2 per cent is biomass-fueled generation. In addition, NSPI has contracts to purchase renewable energy from independent power producers (“IPP”) which own 456 MW of capacity. NSPI owns approximately 5,000 kilometres of transmission facilities and 27,000 kilometres of distribution facilities.

 

Energy from renewable sources will increase upon delivery of the Nova Scotia block (“NS Block”) of electricity transmitted through the Maritime Link from the Muskrat Falls hydroelectric project. The NS Block will provide NSPI with approximately 900 GWh of energy annually for 35 years. In addition, for the first 5 years of the NS Block, NSPI is also entitled to receive approximately 240 GWh of additional energy from the Supplemental Energy Block transmitted through the Maritime Link. NSPI has the option of purchasing additional market-priced energy from Nalcor through the Energy Access Agreement. Nalcor is obligated to offer NSPI a minimum average of 1.2 TWh of energy annually pursuant to this agreement. Delivery of the NS Block is anticipated to commence in 2021.

 

NSPI’s approved regulated ROE range is 8.75 per cent to 9.25 per cent, based on an actual five-quarter average regulated common equity component of up to 40 per cent. NSPI anticipates earning within its allowed ROE range in 2021 and expects rate base and earnings to be higher than 2020. The impact of the COVID-19 pandemic on Nova’s Scotia’s economy and warmer than normal weather adversely affected NSPI’s sales volumes and earnings in 2020. Assuming normal weather and a modest economic recovery in 2021, NSPI expects sales volumes to be higher than 2020. Depending on the duration and severity of the COVID-19 pandemic and the pace and strength of economic recovery, NSPI may continue to experience adverse impacts on sales volumes in 2021.

 

NSPI is currently operating under a three-year fuel stability plan which results in an average annual overall rate increase of 1.5 per cent to recover fuel costs for the period of 2020 through 2022. These rates include recovery of Maritime Link costs (discussed below in the “ENL, NSPML” section).

 

NSPI is subject to environmental laws and regulations set by both the Government of Canada and the Province of Nova Scotia. NSPI continues to work with both levels of government to comply with these laws and regulations to maximize efficiency of emission control measures and minimize customer cost. NSPI anticipates that costs prudently incurred to achieve legislated reductions will be recoverable under NSPI’s regulatory framework.

 

The Government of Canada has laws and regulations that would compel the closure of coal plants before the end of their economic life and at the latest by 2030. The Canada-Nova Scotia Equivalency Agreement allows NSPI to achieve compliance with federal greenhouse gas (“GHG”) emissions regulations. The current Equivalency Agreement, which must be renewed in five year increments, provides equivalency for the 2020-2024 period and outlines the framework for equivalency for the 2025 to 2040 period. At December 31, 2020, NSPI was in compliance with provincial requirements.

 

On November 19, 2020, the Government of Canada introduced Bill C-12, “Canadian Net-Zero Emissions Accountability Act”, which requires national targets be set for the reduction of GHG emissions in Canada, with the objective of attaining net-zero emissions by 2050. NSPI continues to work with the federal government on measures to address their carbon reduction goals.

 

On December 11, 2020, the federal government announced plans to increase the carbon tax in Canada starting in 2023, increasing $15 per tonne annually and reaching $170 per tonne by 2030, under the Greenhouse Gas Pollution Pricing Act (“GGPPA”). The GGPPA is a federal back stop for a price on carbon. As Nova Scotia prices carbon through the Nova Scotia Cap-and-Trade Program Regulations, it is NSPI’s expectation that Nova Scotia’s regulations will be considered equivalent to the proposed carbon tax under the GGPPA. NSPI will continue to work with the provincial government to understand their approach to changes to the Cap-and-Trade Program after 2022 to address the federal government’s plans.

 

EMERA 2020 ANNUAL REPORT 23


 

MANAGEMENT’S DISCUSSION & ANALYSIS

 

NSPI will receive its 2021 granted emissions allowances under the Nova Scotia Cap-and-Trade Program Regulations in Q1 2021. These allowances will be used in 2021 or allocated within the initial four-year compliance period that ends in 2022. NSPI is on track to meet the requirements of the program. NSPI anticipates that any prudently incurred costs required to comply with the Government of Canada’s laws and regulations, and the Nova Scotia Cap-and-Trade Program Regulations, will be recoverable under NSPI’s regulatory framework.

 

Over the past several years, the requirement to reduce Nova Scotia’s reliance upon higher carbon and GHG emitting sources of energy has resulted in NSPI making significant investments in renewable energy sources, including energy from the Maritime Link, and purchasing renewable energy from IPP’s.

 

On March 17, 2020, Nalcor announced that it had paused construction activities at the Muskrat Falls site in response to the COVID-19 pandemic. Nalcor resumed work in May 2020 and continues to work toward construction completion and project commissioning in 2021. Refer to the “ENL, Impact of COVID-19 on Muskrat Falls and LIL” section below for further details. Due to the delay of the NS Block, NSPI did not achieve the provincially legislated target of 40 per cent of electric sales generated from renewable sources in 2020. This would have given rise to non-compliance except that on May 15, 2020, the provincial government provided NSPI with an alternative compliance plan, as permitted by the legislation, which requires NSPI to supply customers with at least 40 per cent of energy generated from renewable sources over the 2020 to 2022 period. NSPI expects to achieve this alternative compliance standard.

 

In 2021, NSPI expects to invest approximately $370 million (2020 – $316 million), including AFUDC, primarily in capital projects to support system reliability and hydroelectric infrastructure renewal investments.

 

ENL

 

NSPML

 

Through its subsidiary, NSPML, ENL has invested $1.9 billion of equity, debt and working capital, including $209 million of AFUDC, in the development of the Maritime Link Project. This investment consists of $546 million in equity, comprised of $443 million in equity contribution and $103 million of accumulated retained earnings, with the remaining being funded with working capital and debt. The project debt has been guaranteed by the Government of Canada.

 

The Maritime Link assets entered service on January 15, 2018 and provides for the transmission of energy and improved reliability and ancillary benefits, supporting the efficiency and reliability of both provinces. The Maritime Link will transmit at greater capacity when the Lower Churchill project is complete.

 

Equity earnings from the Maritime Link are dependent on the approved ROE and operational performance of NSPML. NSPML’s approved regulated ROE range is 8.75 per cent to 9.25 per cent, based on an actual five-quarter average regulated common equity component of up to 30 per cent.

 

On December 16, 2020, the UARB approved NSPML’s 2021 interim cost assessment for recovery from NSPI of Maritime Link costs of approximately $172 million subject to a holdback of $10 million on similar terms as previously approved by the UARB and a potential long-term deferral of up to $23 million in depreciation expense dependent upon the timing of commencement of the NS Block. Recovery of this interim assessment began on January 1, 2021. NSPML expects to file a final cost assessment with the UARB upon commencement of the NS Block of energy from Muskrat Falls which is expected to take place in 2021.

 

In 2021, NSPML expects to invest approximately $15 million (2020 – $7 million) in capital.

 

LIL

 

ENL is a limited partner with Nalcor Energy in LIL, with total project costs estimated at $3.7 billion. Equity earnings are recorded based on an annual ROE of 8.5 per cent of the equity invested. The ROE is approved by the NLPUB.

 

Equity earnings from the LIL investment are based upon the value of the equity investment and the approved ROE. Emera’s current equity investment is $628 million, comprised of $410 million in equity contribution and $218 million of accumulated equity earnings. Emera’s total equity contribution in the LIL, excluding accumulated equity earnings, is estimated to be approximately $650 million after all Lower Churchill projects, including Muskrat Falls, are completed.

 

Cash earnings and return of equity will begin after commissioning of the LIL by Nalcor, and until that point Emera will continue to record AFUDC earnings.

 

Equity earnings from NSPML and LIL are expected to be higher in 2021, compared to 2020. Both the NSPML and LIL investments are recorded as “Investments subject to significant influence” on Emera’s Consolidated Balance Sheets.

 

24 EMERA 2020 ANNUAL REPORT


 

MANAGEMENT’S DISCUSSION & ANALYSIS

 

Impact of COVID-19 on Muskrat Falls and LIL

 

On March 17, 2020, Nalcor announced that it had paused construction activities at the Muskrat Falls site in response to the COVID-19 pandemic. As a result of the effects of COVID-19 on project execution, Nalcor declared force majeure under various project contracts, including formal notification to NSPML. Nalcor resumed work in May 2020. Nalcor achieved first power on the first of four generators at Muskrat Falls on September 22, 2020 and continues to work toward project commissioning in 2021.

 

OTHER ELECTRIC UTILITIES

  

Other Electric Utilities includes Emera (Caribbean) Incorporated (“ECI”), a holding company with regulated electric utilities. ECI’s regulated utilities include vertically integrated regulated electric utilities of BLPC on the island of Barbados, GBPC on Grand Bahama Island, a 51.9 per cent interest in Domlec on the island of Dominica and a 19.5 per cent interest in Lucelec on the island of St. Lucia which is accounted for on the equity basis.

 

On March 24, 2020, Emera completed the sale of Emera Maine which is included in the Other Electric Utilities segment for Q1 2020 and all of 2019. For further detail, refer to the “Significant Items Affecting Earnings” and “Developments” sections.

 

BLPC

 

With approximately $466 million USD of assets and approximately 131,000 customers, BLPC owns 266 MW of generating capacity, of which 96 per cent is oil-fired and four per cent is solar. The utility has an additional 12 MW of capacity from rental units through March 31, 2021. BLPC owns approximately 184 kilometres of transmission facilities and 2,800 kilometres of distribution facilities. BLPC’s approved regulated return on rate base is 10.0 per cent.

 

GBPC

 

With approximately $320 million USD of assets and approximately 19,000 customers, GBPC owns 98 MW of oil-fired generation, approximately 138 kilometres of transmission facilities and 860 kilometres of distribution facilities. The utility has an additional 18 MW of capacity from rental units which are expected to be returned in the first half of 2021, when the generation units damaged by Hurricane Dorian are returned to service. In January 2021, the GBPA approved GBPC’s regulated return on rate base of 8.37 per cent for 2021 (2020 – 8.34 per cent).

 

Domlec

 

Domlec serves approximately 34,000 customers. Domlec owns 26.7 MW of generating capacity, of which 75 per cent is oil-fired and 25 per cent is hydro. Domlec owns approximately 475 kilometres of transmission facilities and 709 kilometres of distribution facilities. Domlec’s approved regulated return on rate base is 15.0 per cent.

 

Other Electric Utilities Outlook

 

Other Electric Utilities’ earnings are expected to increase over the prior year due to higher earnings in 2021 from the Caribbean utilities, partially offset by lower earnings contribution due to the sale of Emera Maine in early 2020. Earnings are expected to increase in 2021 as local economies begin to recover from the impacts of COVID-19 and continued recovery from Hurricane Dorian at GBPC.

 

On November 6, 2020, BLPC notified the Fair Trading Commission (“FTC”) that it plans to file a general rate review application with the FTC in Q1 2021.

 

BLPC operates pursuant to a franchise to generate, transmit and distribute electricity on the island until 2028. In 2019, the Government of Barbados passed legislation amending the number of licenses required for the supply of electricity from a single integrated license which currently exists to multiple licenses for Generation, Transmission and Distribution, Storage, Dispatch and Sales. BLPC is negotiating the terms of the new licenses under the amended legislation.

 

On September 1, 2019, Hurricane Dorian struck Grand Bahama Island causing significant damage across the island. In January 2020, the GBPA approved the recovery of approximately $15 million USD of restoration costs related to GBPC’s self-insured assets. These costs were recorded as a regulatory asset and recovery began January 1, 2021.

 

In 2021, capital investment in the Other Electric Utilities segment is expected to be approximately $165 million USD (2020 – $111 million USD including $14 million USD invested in Emera Maine projects). Forecasted capital investment is primarily in more efficient and cleaner sources of generation, including renewables and battery storage. BLPC expects to complete installation of a 33MW diesel engine in 2021. This 33 MW plant is expected to increase efficiency and bridge BLPC’s transition to increased renewable sources of generation.

 

EMERA 2020 ANNUAL REPORT 25


 

MANAGEMENT’S DISCUSSION & ANALYSIS

 

GAS UTILITIES AND INFRASTRUCTURE

  

Gas Utilities and Infrastructure includes PGS, NMGC, SeaCoast, Brunswick Pipeline and Emera’s non-consolidated investment in M&NP. PGS is a regulated gas distribution utility engaged in the purchase, distribution and sale of natural gas serving customers in Florida. NMGC is a regulated gas distribution utility engaged in the purchase, transmission, distribution and sale of natural gas serving customers in New Mexico. SeaCoast is a regulated intrastate natural gas transmission company offering services in Florida. Brunswick Pipeline is a regulated 145-kilometre pipeline delivering re-gasified liquefied natural gas from Saint John, New Brunswick, to markets in the northeastern United States.

 

Peoples Gas System

 

With approximately $1.6 billion USD of assets and approximately 426,000 customers, the PGS system includes approximately 22,200 kilometres of natural gas mains and 12,600 kilometres of service lines. Natural gas throughput (the amount of gas delivered to its customers, including transportation-only service) was 2.1 billion therms in 2020.

 

For 2020, the approved ROE range for PGS was 9.25 per cent to 11.75 per cent, based on an allowed equity capital structure of 54.7 per cent. An ROE of 10.75 per cent was used for the calculation of return on investments for clauses. Beginning in 2021, the approved ROE range is 8.9 per cent to 11.0 per cent, based on an allowed equity capital structure of 54.7 per cent and an ROE of 9.9 per cent will be used for the calculation of return on investments for clauses. See below for further detail.

 

New Mexico Gas Company, Inc.

 

With approximately $1.5 billion USD of assets and approximately 540,000 customers, NMGC serves approximately 60 per cent of New Mexico’s population in 23 of the state’s 33 counties. NMGC’s system includes approximately 2,443 kilometres of transmission pipelines and 17,243 kilometres of distribution pipelines. Annual natural gas throughput was approximately 948 million therms in 2020.

 

For 2020, the approved ROE for NMGC was 9.1 per cent, on an allowed equity capital structure of 52 per cent. New rates became effective August 2019 and were phased in over two years resulting in an annual revenue increase of approximately $3 million USD. In addition, NMGC’s weather mechanism became effective October 2019. Beginning in 2021, the approved ROE is 9.375 per cent on an allowed equity capital structure of 52 per cent. See below for further detail.

 

Gas Utilities and Infrastructure Outlook

 

Gas Utilities and Infrastructure earnings are anticipated to be higher in 2021 than 2020 primarily due to rate base growth to expand the distribution system and to continue to reliably serve customers.

 

PGS anticipates earning within its allowed ROE range in 2021 and expects rate base and earnings to be higher than in 2020. PGS expects customer growth in 2021 to be higher than Florida’s population growth rates, reflecting expectations of continued strong housing demand in Florida and commercial activity trending back towards normal levels. Assuming normal weather, PGS sales volumes are expected to increase above customer growth, as the COVID-19 pandemic impact on 2021 commercial energy sales is expected to be less than 2020. In January 2021, a base rate increase went into effect in accordance with the FPSC approved rate case settlement and is expected to result in a $34 million USD revenue increase.

 

PGS was permitted to initiate a general base rate proceeding during 2020, provided the new rates do not become effective before January 1, 2021. On June 8, 2020, PGS filed a petition for an increase in rates and service charges effective January 2021. On November 19, 2020, the FPSC approved a settlement agreement filed by PGS. The settlement agreement allows for an increase in base rates by $58 million USD annually effective January 2021, which is a $34 million USD increase in revenue and $24 million USD increase of revenues previously recovered through the cast iron and bare steel replacement rider. This settlement agreement includes an allowed regulatory ROE range of 8.9 per cent to 11.0 per cent with a 9.9 per cent midpoint. It provides PGS the ability to reverse a total of $34 million USD of accumulated depreciation through 2023 and sets new depreciation rates going into effect January 1, 2021 that are consistent with PGS’ current overall average depreciation rate. Under the agreement base rates are frozen from January 1, 2021 to December 31, 2023, unless its earned ROE were to fall below 8.9 per cent before that time with an allowed equity in the capital structure of 54.7 per cent from investor sources of capital. The settlement agreement provides for the deferral of income taxes as a result of changes in tax laws. The changes would be reflected as a regulatory asset or liability and either result in an increase or a decrease in customer rates through a subsequent regulatory process.

 

26 EMERA 2020 ANNUAL REPORT


 

MANAGEMENT’S DISCUSSION & ANALYSIS

 

NMGC anticipates earning at or near its authorized ROE in 2021 and expects rate base to be higher than 2020. NMGC expects customer growth rates to be consistent with historical trends.

 

NMGC filed a rate case in December 2019. NMGC reached an unopposed stipulated settlement of the case which was approved by the NMPRC in December 2020. The new rates reflect the recovery of capital investment in pipelines and related infrastructure and results in an increase in revenue of approximately $5 million USD annually effective January 2021. The stipulated settlement agreement includes an allowed regulatory ROE of 9.375 per cent on an allowed equity capital structure of 52 per cent. Under the agreement base rates are frozen from January 1, 2021 to December 31, 2022, unless new federal tax rates are enacted, in which case NMGC can file for new rates to be effective earlier than January 1, 2023.

 

In 2018, SeaCoast executed an agreement with Seminole Electric Cooperative, Inc. (“Seminole”) to provide long-term firm gas transportation service to Seminole’s new gas-fired generating facility being constructed in Putnam County, Florida. SeaCoast is constructing and will operate a 21-mile, 30-inch pipeline lateral that will be treated as a sales-type lease for accounting purposes. The lease of the pipeline lateral to Seminole is anticipated to commence in January 2022. The capital investment is projected to be approximately $100 million USD, with the majority of the project investment completed through 2020. SeaCoast also jointly developed the 26.5 mile, 16-inch Callahan Pipeline with Peninsula Pipeline Co., an affiliate of Florida Public Utilities. The SeaCoast pipeline went into service in Q4 2020 providing long-term firm gas transportation service to PGS in the northeast Florida area with 2021 being the first full year of operation. SeaCoast’s portion of the capital investment in the Callahan Pipeline was approximately $30 million USD.

 

In 2021, capital investment in the Gas Utilities and Infrastructure segment is expected to be approximately $425 million USD (2020 – $553 million USD), including AFUDC. PGS will make investments to expand its system and support customer growth. NMGC completed the Santa Fe Mainline Looping project in January 2021 and will continue to invest in system improvements.

 

OTHER

 

The Other segment includes those business operations that in a normal year are below the required threshold for reporting as separate segments; and corporate expense and revenue items that are not directly allocated to the operations of Emera’s subsidiaries and investments.

 

Business operations in Other include Emera Energy, which consists of:

 

Emera Energy Services (“EES”), a wholly owned physical energy marketing and trading business; and

an equity investment in a 50.0 per cent joint venture ownership of Bear Swamp, a 600 MW pumped storage hydroelectric facility in northwestern Massachusetts.

 

Corporate items included in the Other segment are certain corporate-wide functions including executive management, strategic planning, treasury services, legal, financial reporting, tax planning, corporate business development, corporate governance, investor relations, risk management, insurance, acquisition and disposition related costs, gains or losses on select assets sales, and corporate human resource activities. It includes interest revenue on intercompany financings recorded in “Intercompany revenue” and interest expense on corporate debt in both Canada and the US. It also includes costs associated with corporate activities that are not directly allocated to the operations of Emera’s subsidiaries and investments.

 

Earnings from EES are generally dependent on market conditions. In particular, volatility in electricity and natural gas markets, which can be influenced by weather, local supply constraints and other supply and demand factors, can provide higher levels of margin opportunity. The business is seasonal, with Q1 and Q4 usually providing the greatest opportunity for earnings. EES is generally expected to deliver annual adjusted net earnings of $15 to $30 million USD ($45 to $70 million USD of margin), with the opportunity for upside when market conditions present. The COVID-19 related economic slowdown did not have a material impact on EES earnings in 2020. The pandemic remains a challenge to the overall economy but is expected to continue to have limited impact on EES operations unless circumstances deteriorate significantly.

 

Absent the gain on the TGH award in 2020, the adjusted net loss from the Other segment is expected to be lower in 2021, based on EES returning to its normal earnings range.

 

In 2021, capital investment in the Other segment is expected to be approximately $2 million (2020 – $3 million).

 

EMERA 2020 ANNUAL REPORT 27


 

MANAGEMENT’S DISCUSSION & ANALYSIS

 

CONSOLIDATED BALANCE SHEET HIGHLIGHTS

 

Significant changes in the Consolidated Balance Sheets between December 31, 2019 and December 31, 2020 include:

 

millions of Canadian dollars Increase
(Decrease)
Explanation
Assets    
Receivables and other assets (current and long-term) (226) Decreased due to the refund of corporate alternative minimum tax credit (“AMT”) carryforwards, lower gas transportation assets at Emera Energy, a refund of prior year income taxes receivable at NSPI, cash collateral positions on derivative instruments at NSPI and lower commodity prices at Emera Energy.
Assets held for sale (current and long-term), net of liabilities (691) Decreased due to the sale of Emera Maine.
Property, plant and equipment, net of accumulated depreciation and amortization 1,368  Increased due to capital additions at Tampa Electric, PGS and NSPI, partially offset by the effect of a stronger CAD on the translation of Emera’s foreign affiliates.
Goodwill (115) Decreased due to the effect of a stronger CAD on the translation of Emera’s foreign affiliates.
Liabilities and Equity    
Short-term debt and long-term debt (including current portion) (371) Decreased due to net repayments on committed credit facilities at TECO Finance, Emera and NSPI, repayment of long-term debt at TECO Finance, and the effect of a stronger CAD on the translation of Emera’s foreign affiliates. This was partially offset by a net issuance on committed credit facilities at Tampa Electric and PGS and issuance of long-term debt at NSPI.
Deferred income tax liabilities, net of deferred income tax assets 321  Increased due to net utilization of tax loss carryforwards primarily related to the sale of Emera Maine, and tax deductions in excess of accounting depreciation related to property, plant and equipment. The increase was partially offset by the revaluation of net deferred income tax liabilities resulting from enactment of a lower Nova Scotia provincial corporate income tax rate in Q1 2020 and the effect of a stronger CAD on the translation of Emera’s foreign subsidiaries.
Regulatory liabilities (current and long-term) (220) Decreased due to changes in the fuel adjustment mechanism deferral and derivative instrument deferrals at NSPI, decreased deferred income tax regulatory liabilities primarily due to amortization of excess deferred income taxes related to US Tax Reform at Tampa  Electric, PGS and NMGC, and the effect of a stronger CAD on the translation of Emera’s foreign affiliates.
Common stock 489  Increased due to shares issued under Emera’s at-the-market equity plan, the dividend reinvestment plan and stock options exercised.
Accumulated other comprehensive income (174) Decreased due to the effect of a stronger CAD on the translation of Emera’s foreign affiliates.
Retained earnings 322 

Increased due to the gain on sale of Emera Maine and net income in excess of dividends paid.

 

28 EMERA 2020 ANNUAL REPORT


 

MANAGEMENT’S DISCUSSION & ANALYSIS

 

DEVELOPMENTS

 

Increase in Common Dividend

 

On September 16, 2020, Emera’s Board of Directors approved an increase in the annual common share dividend rate to $2.55 from $2.45. The first payment was effective November 16, 2020. Emera also reaffirmed its four to five per cent annual dividend growth rate target through 2022.

 

Sale of Emera Maine

 

On March 24, 2020, Emera completed the sale of Emera Maine for a total enterprise value of $2.0 billion ($1.4 billion USD), including cash proceeds of $1.4 billion, transferred debt and a working capital adjustment. A gain on sale of $309 million after tax, net of transaction costs, was recognized in the Other segment. Proceeds from the sale were used to support capital investment opportunities within Emera’s regulated utilities and to reduce corporate debt.

 

Tampa Electric Solar Investment

 

On February 18, 2020, Tampa Electric announced its intention to invest approximately $800 million USD in an additional 600 MW of new utility-scale solar photovoltaic projects by the end of 2023. On completion of these projects, approximately 22 per cent, or 1,250 MW, of Tampa Electric’s total generating capacity will be solar.

 

APPOINTMENTS

 

Board of Directors

 

Effective February 12, 2021, Karen Sheriff joined the Emera Board of Directors. Most recently, Ms. Sheriff served as President and Chief Executive Officer of Q9 Networks Inc., a data centre services provider. Before that, she was President and Chief Executive Officer of Bell Aliant, Inc., a telecommunications company.

 

Executive

 

On February 9, 2021, Emera announced that Archie Collins was appointed President and Chief Executive Officer of Tampa Electric Company effective May 3, 2021. Until that time, Mr. Collins will serve as President and Chief Operating Officer and was most recently the Chief Operating Officer of Tampa Electric Company. Mr. Collins will succeed Nancy Tower who is retiring in June 2021.

 

Effective October 14, 2020, Peter Gregg was appointed President and CEO of NSPI. Most recently, Mr. Gregg was the President and CEO of the Independent Electricity System Operator in Ontario. Mr. Gregg succeeded Richard Janega, who was appointed interim President and CEO of NSPI effective June 1, 2020. Mr. Janega is Emera’s Chief Operating Officer, Electric Utilities, Canada, US Northeast and Caribbean.

 

EMERA 2020 ANNUAL REPORT 29


 

MANAGEMENT’S DISCUSSION & ANALYSIS

 

OUTSTANDING COMMON STOCK DATA

 

Common stock
Issued and outstanding:
millions of shares   millions of
Canadian dollars
Balance, December 31, 2018 234.12 $ 5,816
Conversion of Convertible Debentures 0.03 1
Issuance of common stock (1) 1.77 99
Issued for cash under Purchase Plans at market rate 3.99 202
Discount on shares purchased under Dividend Reinvestment Plan (7 )
Options exercised under senior management stock option plan 2.57 104
Employee Share Purchase Plan 1
Balance, December 31, 2019 242.48 $ 6,216
Issuance of common stock (2) 4.54 251
Issued for cash under Purchase Plans at market rate 3.99 219
Discount on shares purchased under Dividend Reinvestment Plan (4 )
Options exercised under senior management stock option plan 0.42 20
Employee Share Purchase Plan 3
Balance, December 31, 2020 251.43 $ 6,705
(1) As at December 31, 2019, 1,768,120 common shares were issued under Emera’s at-the-market program (“ATM program”) at an average price of $56.56 per share for gross proceeds of $100 million ($99 million net of issuance costs).

(2) In Q4 2020, 1,835,422 common shares were issued under Emera’s ATM program at an average price of $55.19 per share for gross proceeds of $102 million ($100 million net of issuance costs). For the year ended December 31, 2020, 4,544,025 common shares were issued under Emera’s ATM program at an average price of $56.04 per share for gross proceeds of $255 million ($251 million net of issuance costs). As at December 31, 2020, an aggregate gross sales limit of $245 million remains available for issuance under the ATM program.

 

As at February 9, 2021, the amount of issued and outstanding common shares was 251.6 million.

 

The weighted average shares of common stock outstanding – basic, which includes both issued and outstanding common stock and outstanding deferred share units, for the three months ended December 31, 2020 was 251.3 million (2019 – 242.9 million). The weighted average shares of common stock outstanding – basic for the year ended December 31, 2020 was 247.8 million (2019 – 239.9 million).

 

At-The-Market Equity Program 

On November 17, 2020, Emera filed an amendment to its July 11, 2019 prospectus supplement which established its ATM program. This amendment reflected changes in securities regulations related to ATM programs which were effective August 31, 2020. The amendment includes removal of the daily trading limit which previously provided that the number of shares sold could not exceed 25 per cent of the daily trading volume of the shares.

 

Cumulative Preferred Stock 

For details regarding cumulative preferred stock, refer to note 28 in Emera’s 2020 annual audited financial statements, with updates as noted below:

 

On July 9, 2020, Emera announced it would not redeem the Cumulative Rate Reset Preferred Shares, Series A (“Series A Shares”) or the Cumulative Floating Rate First Preferred Shares, Series B (“Series B Shares”). On August 17, 2020, Emera announced 128,610 of its 3,864,636 issued and outstanding Series A Shares were tendered for conversion into Series B Shares and 1,130,788 of its 2,135,364 issued and outstanding Series B Shares were tendered for conversion into Series A Shares, all on a one-for-one basis. As a result of the conversion, Emera has 4,866,814 Series A Shares and 1,133,186 Series B Shares issued and outstanding.

 

On July 16, 2020, Emera announced a dividend rate of 2.182 per cent per annum on the Series A Shares during the five-year period which commenced on August 15, 2020 and ends on (and inclusive of) August 14, 2025 ($0.1364 per Series A Share per quarter). Emera also announced a dividend rate of 2.021 per cent on the Series B Shares for the three-month period which commenced on August 15, 2020 and ended on (and inclusive of) November 14, 2020 ($0.1274 per Series B Share for the quarter).

 

30 EMERA 2020 ANNUAL REPORT


 

MANAGEMENT’S DISCUSSION & ANALYSIS

 

FINANCIAL HIGHLIGHTS

 

FLORIDA ELECTRIC UTILITY

 

All amounts are reported in USD, unless otherwise stated.

 

For the
millions of US dollars (except per share amounts)
Three months ended
December 31
Year ended
December 31
2020 2019 2020 2019
Operating revenues – regulated electric $ 468 $ 473 $ 1,849 $ 1,965
Regulated fuel for generation and purchased power $ 127 $ 143 $ 428 $ 582
Contribution to consolidated net income $ 76 $ 61 $ 372 $ 316
Contribution to consolidated net income – CAD $ 101 $ 80 $ 501 $ 419
Contribution to consolidated earnings per common share – basic – CAD $ 0.40 $ 0.33 $ 2.02 $ 1.75
Net income weighted average foreign exchange rate – CAD/USD $ 1.31 $ 1.32 $ 1.34 $ 1.33
                           
EBITDA $ 201 $ 187 $ 891 $ 828
EBITDA – CAD $ 263 $ 245 $ 1,196 $ 1,098

 

Net Income 

Highlights of the net income changes are summarized in the following table:

 

For the

millions of US dollars

Three months ended
December 31
Year ended
December 31
Contribution to consolidated net income – 2019 $ 61 $ 316
Decreased operating revenues – see Operating Revenues – Regulated Electric below (5 ) (116 )
Decreased fuel for generation and purchased power – see Regulated Fuel for Generation and Purchased Power below 16 154
Increased depreciation due to increased property, plant and equipment (4 ) (19 )
Decreased amortization expenses resulting from a credit to accumulated amortization reserve surplus for intangible software assets as approved by the regulator 4 16
Increased AFUDC earnings due to the Big Bend Power Station modernization and solar projects 5 15
Other (1 ) 6
Contribution to consolidated net income – 2020 $ 76 $ 372

 

Florida Electric Utility’s CAD contribution to consolidated net income increased $21 million in Q4 2020, compared to Q4 2019. For the year ended December 31, 2020, Florida Electric Utility’s CAD contribution to consolidated net income increased $82 million, compared to 2019. The increase in both periods was due to increased base revenues, as described below, and higher AFUDC earnings as a result of the Big Bend Power Station modernization and solar projects. Operating revenues decreased due to lower clause revenues; however, base revenues increased as a result of the in-service of solar generation projects, a greater mix of residential sales related to COVID-19, warmer weather than in the prior year and customer growth.

 

The impact of the change in the foreign exchange rate decreased CAD earnings for the quarter by $1 million and increased CAD earnings at year ended December 31, 2020 by $6 million.

 

EMERA 2020 ANNUAL REPORT 31


 

MANAGEMENT’S DISCUSSION & ANALYSIS

 

Operating Revenues – Regulated Electric 

Electric revenues decreased $5 million to $468 million in Q4 2020, compared to $473 million in Q4 2019. For the year ended December 31, 2020, electric revenues decreased $116 million to $1,849 million, from $1,965 million in 2019. The decreases in both periods were due to lower clause revenues as a result of a decrease in fuel cost, partially offset by the in-service of solar generation projects, predominately warmer weather than in prior year, a greater mix of residential sales related to COVID-19 and customer growth.

 

Electric revenues and sales volumes are summarized in the following tables by customer class:

 

Q4 Electric Revenues

 

millions of US dollars
2020 2019
Residential $ 256 $ 254
Commercial 132 141
Industrial 34 39
Other (1) 46 39
Total $ 468 $ 473
(1) Other includes sales to public authorities, off-system sales to other utilities and regulatory deferrals related to clauses.

Annual Electric Revenues

 

millions of US dollars
2020 2019
Residential $ 1,018 $ 1,046
Commercial 506 562
Industrial 133 156
Other (1) 192 201
Total $ 1,849 $ 1,965
(1) Other includes sales to public authorities, off-system sales to other utilities and regulatory deferrals related to clauses.


Q4 Electric Sales Volumes

 

Gigawatt hours (“GWh”)
2020 2019
Residential 2,465 2,303
Commercial 1,526 1,536
Industrial 460 501
Other 515 579
Total 4,966 4,919

Annual Electric Sales Volumes

 

GWh
2020 2019
Residential 10,122 9,584
Commercial 6,058 6,240
Industrial 1,891 2,021
Other 1,958 2,094
Total 20,029 19,939


Regulated Fuel for Generation and Purchased Power 

Tampa Electric is required to maintain a generating capacity greater than firm peak demand. The total Tampa Electric-owned generation capacity is 5,790 MW. Tampa Electric meets the planning criteria for reserve capacity established by the FPSC, which is a 20 per cent reserve margin over firm peak demand.

 

Regulated fuel for generation and purchased power decreased $16 million to $127 million in Q4 2020, compared to $143 million in Q4 2019. For the year ended December 31, 2020, regulated fuel for generation and purchased power decreased $154 million to $428 million, compared to $582 million in 2019. The decrease in both periods was due to lower natural gas prices and increased solar generation.

 

Q4 Production Volumes

 

GWh
2020 2019
Natural gas 3,616 4,075
Coal 344 323
Solar 232 169
Purchased power 747 210
Total 4,939 4,777

Annual Production Volumes

 

GWh
2020 2019
Natural gas 16,523 17,514
Coal 904 1,214
Solar 1,120 756
Purchased power 2,513 1,290
Total 21,060 20,774


Q4 Average Fuel Costs

 

US dollars
2020 2019
Dollars per Megawatt hour (“MWh”) $ 26 $ 30

Annual Average Fuel Costs

 

US dollars
2020 2019
Dollars per MWh $ 20 $ 28


32 EMERA 2020 ANNUAL REPORT


 

MANAGEMENT’S DISCUSSION & ANALYSIS

 

Tampa Electric’s fuel costs are affected by commodity prices and generation mix that is largely dependent on economic dispatch of the generating fleet, bringing the lowest cost options on first (renewable energy from solar), such that the incremental cost of production increases as sales volumes increase. Generation mix may also be affected by plant outages, plant performance, availability of lower priced short-term purchased power, availability of renewable solar generation, and compliance with environmental standards and regulations.

 

Average fuel cost per MWh decreased in Q4 2020 and for the year ended December 31, 2020, compared to 2019, due to lower natural gas prices and increased use of solar generation which has no fuel cost.

 

Regulatory Recovery Mechanisms 

Tampa Electric is regulated by FPSC. Tampa Electric is also subject to regulation by the FERC. The FPSC sets rates at a level that allows utilities such as Tampa Electric to collect total revenues or revenue requirements equal to their cost of providing service, plus an appropriate return on invested capital. Base rates are determined in FPSC rate setting hearings which occur at the initiative of Tampa Electric, the FPSC or other interested parties.

 

Solar Base Rate Adjustments Included in Base Rates 

As of December 31, 2020, Tampa Electric has invested $820 million USD in 600 MW of utility-scale solar photovoltaic projects, which are recoverable through FPSC-approved solar base rate adjustments (“SoBRAs”). Tampa Electric expects to invest an additional $30 million USD in these projects through 2021. AFUDC is being earned on these projects during construction. The FPSC has approved SoBRAs representing a total of 600 MW or $104 million USD annually in estimated revenue requirements for in-service projects.

 

The true-up filing for SoBRAs tranche 1 and 2 revenue requirement estimates that were included in base rates as of September 2018 and January 2019, respectively, was submitted on April 30, 2020, and the FPSC approved the amount on August 18, 2020. A $5 million USD true-up was returned to customers in 2020. The true-ups for SoBRA tranches 3 and 4 will be filed in 2021 and 2022, respectively.

 

Other Cost Recovery

 

Fuel Recovery Clause 

Tampa Electric has a fuel recovery clause approved by the FPSC, allowing the opportunity to recover fluctuating fuel expenses from customers through annual fuel rate adjustments. Differences between prudently incurred fuel costs and amounts recovered from customers through electricity rates in a year are deferred to a fuel clause regulatory asset or liability and recovered from or returned to customers in a subsequent year.

 

Storm Protection Plan Cost Recovery Clause 

Tampa Electric has a Storm Protection Plan cost recovery clause allowing recovery of prudent transmission and distribution storm hardening costs for incremental activities not already included in base rates as outlined in the programs in its approved Storm Protection Plan. Differences between the prudently incurred clause-recoverable costs and amounts recovered from customers through electricity rates in a year are deferred and recovered from or returned to customers in a subsequent year.

 

Other Cost Recovery Clauses 

The FPSC annually approves cost-recovery rates for purchased power, capacity, environmental and conservation costs including a return on capital invested. Differences between the prudently incurred clause-recoverable costs and amounts recovered from customers through electricity rates in a year are deferred to a corresponding regulatory asset or liability and recovered from or returned to customers in a subsequent year.

 

Storm Reserve 

The storm reserve is for hurricanes and other named storms that cause significant damage to Tampa Electric’s system. Tampa Electric can petition the FPSC to seek recovery of restoration costs over a 12-month period, or longer, as determined by the FPSC, as well as to replenish the reserve.

 

EMERA 2020 ANNUAL REPORT 33


 

MANAGEMENT’S DISCUSSION & ANALYSIS

 

CANADIAN ELECTRIC UTILITIES

 

For the
millions of Canadian dollars (except per share amounts)
Three months ended
December 31
Year ended
December 31
2020 2019 2020 2019
Operating revenues – regulated electric $ 377 $ 364 $ 1,494 $ 1,430
Regulated fuel for generation and purchased power (1) $ 219 $ 183 $ 721 $ 663
Income from equity investments $ 21 $ 23 $ 96 $ 91
Contribution to consolidated net income $ 57 $ 58 $ 221 $ 229
Contribution to consolidated earnings per common share – basic $ 0.23 $ 0.24 $ 0.89 $ 0.95
                           
EBITDA $ 157 $ 151 $ 614 $ 592
(1) Regulated fuel for generation and purchased power includes NSPI’s Fuel Adjustment Mechanism (“FAM”) and fixed cost deferrals on the Consolidated Statements of Income, however it is excluded in the segment overview.

 

Canadian Electric Utilities’ contribution to consolidated net income is summarized in the following table:

 

For the
millions of Canadian dollars
Three months ended
December 31
Year ended
December 31
2020 2019 2020 2019
NSPI $ 36 $ 35 $ 125 $ 138
Equity investment in LIL 12 12 49 45
Equity investment in NSPML 9 11 47 46
Contribution to consolidated net income $ 57 $ 58 $ 221 $ 229

 

Net Income 

Highlights of the net income changes are summarized in the following table:

 

For the
millions of Canadian dollars
Three months ended
December 31
Year ended
December 31
Contribution to consolidated net income – 2019 $ 58 $ 229
Increased operating revenues – see Operating Revenues – Regulated Electric below 13 64
Increased fuel for generation and purchased power – see Regulated Fuel for Generation and Purchased Power below (36 ) (58 )
Decreased FAM expense in the quarter primarily due to the refund of prior years’ over-recovery of fuel costs, partially offset by increased recoveries of current period fuel costs. Year-over-year increase in FAM expense due to over recoveries of current period fuel costs and the prior year recovery of the reduced Maritime Link assessment returned to customers in subsequent years. This was partially offset by the refund of customers of prior years’ over-recovery of fuel costs. 12 (28 )
Decreased OM&G expense quarter-over-quarter primarily due to lower labour costs, storm restoration costs, power generation and vegetation management costs and decreased demand side management (“DSM”) expense. Year-over-year these decreases were partially offset by lower overhead allocated to property, plant and equipment, and COVID-19 pandemic response costs. 14 31
Increased year-over-year due to increased equity earnings from the LIL (1 ) 5
Increased income taxes primarily due to a reduction in the non-capital loss carryback as a result of lower tax deductions in excess of accounting depreciation related to property, plant and equipment and the tax benefits of capital investment related to post-tropical storm Dorian in 2019. (5 ) (27 )
Other 2 5
Contribution to consolidated net income – 2020 $ 57 $ 221

 

Canadian Electric Utilities’ contribution to consolidated net income decreased $1 million to $57 million in Q4 2020, compared to $58 million for the same period in 2019. For the year ended December 31, 2020 Canadian Electric Utilities’ contribution to consolidated net income decreased $8 million to $221 million compared to $229 million in 2019. The decrease in both periods was due to higher income tax expense, warmer weather than prior year, and lower commercial sales related to COVID-19, partially offset by decreased OM&G expense and increased mix of residential sales related to COVID-19 at NSPI.

 

The timing of regulatory deferrals causes quarterly earnings volatility, while full year results are more predictable.

 

34 EMERA 2020 ANNUAL REPORT


 

MANAGEMENT’S DISCUSSION & ANALYSIS

 

NSPI

 

Operating Revenues – Regulated Electric 

Operating revenues increased $13 million to $377 million in Q4 2020, compared to $364 million in Q4 2019. For the year ended December 31, 2020, operating revenues increased $64 million to $1,494 million, compared to $1,430 million in 2019. The increase in both periods was primarily due to a higher Maritime Link assessment included in revenue compared to 2019, increased fuel-related pricing, and higher residential sales volumes related to COVID-19. This was partially offset by decreased sales volumes due to warmer weather than prior year and decreased commercial sales volumes primarily due to the impact of the COVID-19 pandemic. Quarter-over-quarter was also impacted by increased industrial sales volumes. Year-over-year was also partially offset by decreased other sales volumes.

 

Electric revenues and sales volumes are summarized in the following tables by customer class:

 

Q4 Electric Revenues

 

millions of Canadian dollars            
    2020     2019  
Residential   $ 199     $ 194  
Commercial     102       102  
Industrial     60       50  
Other     7       10  
Total   $ 368     $ 356  

 

Q4 Electric Sales Volumes

 

GWh              
      2020     2019  
Residential       1,159       1,210  
Commercial       712       763  
Industrial       629       571  
Other       36       78  
Total       2,536       2,622  

Annual Electric Revenues

 

millions of Canadian dollars            
    2020     2019  
Residential   $ 806     $ 746  
Commercial     405       400  
Industrial     224       210  
Other     31       45  
Total   $ 1,466     $ 1,401  

 

Annual Electric Sales Volumes

 

GWh              
      2020     2019  
Residential       4,652       4,664  
Commercial       2,850       3,068  
Industrial       2,341       2,388  
Other       185       350  
Total       10,028       10,470  


 

Regulated Fuel for Generation and Purchased Power 

Regulated fuel for generation and purchased power increased $36 million to $219 million in Q4 2020, compared to $183 million in Q4 2019. For the year ended December 31, 2020, regulated fuel for generation and purchased power increased $58 million to $721 million, compared to $663 million in 2019. Changes in both periods were primarily due to higher Maritime Link assessment costs in 2020, changes in generation mix, and increased commodity prices, partially offset by decreased sales volumes.

 

Q4 Production Volumes

 

GWh            
    2020     2019  
Coal     1,249       1,398  
Natural gas     351       322  
Oil and petcoke     174       149  
Purchased power – other     235       139  
Total non-renewables     2,009       2,008  
Purchased power – IPP     353       371  
Wind and hydro     215       306  
Purchased power – Community Feed-in Tariff program (“COMFIT”)     156       163  
Biomass     21       14  
Total renewables     745       854  
Total production volumes     2,754       2,862  

Annual Production Volumes

 

GWh            
    2020     2019  
Coal     4,342       4,949  
Natural gas     1,872       1,369  
Oil and petcoke     967       981  
Purchased power – other     663       786  
Total non-renewables     7,844       8,085  
Purchased power – IPP     1,250       1,202  
Wind and hydro     1,001       1,289  
Purchased power – COMFIT     558       552  
                 
Biomass     106       73  
Total renewables     2,915       3,116  
Total production volumes     10,759       11,201  


 

EMERA 2020 ANNUAL REPORT 35


 

MANAGEMENT’S DISCUSSION & ANALYSIS

 

Q4 Average Fuel Costs

 

      2020     2019  
Dollars per MWh     $ 80     $ 64  

Annual Average Fuel Costs

 

      2020     2019  
Dollars per MWh     $ 67     $ 59  


Average fuel cost per MWh increased in Q4 2020 compared to Q4 2019 due to higher Maritime Link assessment costs in 2020 and increased commodity pricing. For the year ended December 31, 2020 compared to the same period in 2019, fuel costs increased due to a change in generation mix resulting from higher natural gas consumption and lower generation from NSPI owned hydro and wind, which have no fuel cost. This was partially offset by lower generation from solid fuel.

 

NSPI’s FAM regulatory liability balance decreased $94 million from $115 million at December 31, 2019 to $21 million at December 31, 2020, primarily due to the refund of prior years’ over-recovery of fuel costs and reduced 2019 Maritime Link assessment refunded to customers in 2020. This was partially offset by over-recovery of current-period fuel costs.

 

NSPI’s fuel costs are affected by commodity prices and generation mix, which is largely dependent on economic dispatch of the generating fleet, bringing the lowest cost options on stream first after renewable energy from IPPs including COMFIT participants, for which NSPI has power purchase agreements in place.

 

NSPI-owned hydro and wind have no fuel cost component. After hydro and wind, historically, petcoke and coal have the lowest per unit fuel cost, followed by natural gas. Oil, biomass and purchased power have the next lowest fuel cost, depending on the relative pricing of each. Generation mix may also be affected by plant outages, availability of renewable generation, plant performance and compliance with environmental standards and regulations.

 

The generation mix has transformed with the addition of new non-dispatchable renewable energy sources such as wind, including IPP and COMFIT, which typically have a higher cost per MWh than NSPI-owned generation or other purchased power sources.

 

Regulatory Recovery Mechanisms

 

NSPI 

NSPI is a public utility as defined in the Public Utilities Act of Nova Scotia (the “Public Utilities Act”) and is subject to regulation under the Public Utilities Act by the UARB. The Public Utilities Act gives the UARB supervisory powers over NSPI’s operations and expenditures. Electricity rates for NSPI’s customers are subject to UARB approval. NSPI is not subject to a general annual rate review process, but rather participates in hearings held from time to time at NSPI’s or the UARB’s request.

 

NSPI is regulated under a cost-of-service model, with rates set to recover prudently incurred costs of providing electricity service to customers and provide a reasonable return to investors.

 

NSPI has a FAM, approved by the UARB, allowing NSPI to recover fluctuating fuel costs from customers through fuel rate adjustments. Differences between prudently incurred fuel costs and amounts recovered from customers through electricity rates in a year are deferred to a FAM regulatory asset or liability.

 

As part of the three-year fuel stability plan, electricity rates have been set to include the $145 million approved Maritime Link assessment for 2020 and amounts of $164 million and $162 million for 2021 and 2022, respectively. On December 16, 2020, the UARB approved NSPML’s 2021 interim cost assessment recovery from NSPI of Maritime Link costs of approximately $172 million subject to a holdback of $10 million on similar terms as previously approved by the UARB and a potential long-term deferral of up to $23 million in depreciation expense dependent upon the timing of commencement of the NS Block. Refer to the NSPML section below for further details. Any difference between the amounts included in the fuel stability plan and those approved by the UARB through the NSPML interim assessment application will be addressed through the FAM.

 

36 EMERA 2020 ANNUAL REPORT


 

MANAGEMENT’S DISCUSSION & ANALYSIS

 

OTHER ELECTRIC UTILITIES 

All amounts are reported in USD, unless otherwise stated.

 

On March 24, 2020, Emera completed the sale of Emera Maine. For further detail, refer to the “Significant Items Affecting Earnings” and “Developments” sections.

 

For the

millions of US dollars (except per share amounts)

  Three months ended
December 31
    Year ended
December 31
 
    2020     2019     2020     2019  
Operating revenues – regulated electric   $ 79     $ 140     $ 354     $ 561  
Regulated fuel for generation and purchased power (1)     35       58       145       216  
Adjusted contribution to consolidated net income   $ 5     $ 10     $ 24     $ 57  
Adjusted contribution to consolidated net income – CAD   $ 8     $ 14     $ 33     $ 76  
Impairment charges           (26 )           (26 )
After-tax equity securities MTM gain     2             2       2  
Contribution to consolidated net income   $ 7     $ (16 )   $ 26     $ 33  
Contribution to consolidated net income – CAD   $ 10     $ (19 )   $ 35     $ 45  
Adjusted contribution to consolidated earnings per common share – basic – CAD   $ 0.03     $ 0.06     $ 0.13     $ 0.32  
Contribution to consolidated earnings per common share – basic – CAD   $ 0.04     $ (0.08 )   $ 0.14     $ 0.19  
Net income weighted average foreign exchange rate – CAD/USD   $ 1.28     $ 1.32     $ 1.34     $ 1.33  
                                 
Adjusted EBITDA   $ 19     $ 38     $ 96     $ 187  
Adjusted EBITDA – CAD   $ 27     $ 52     $ 129     $ 249  

(1) Regulated fuel for generation and purchased power includes transmission pool expense.

 

Other Electric Utilities’ adjusted contribution is summarized in the following table:

 

For the
millions of US dollars
  Three months ended
December 31
    Year ended
December 31
 
    2020     2019     2020     2019  
ECI   $ 5     $ 3     $ 20     $ 22  
Emera Maine           7       4       35  
Adjusted contribution to consolidated net income   $ 5     $ 10     $ 24     $ 57  

 

Net Income 

Highlights of the net income changes are summarized in the following table:

 

For the
millions of US dollars
  Three months ended
December 31
    Year ended
December 31
 
Contribution to consolidated net income – 2019   $ (16 )   $ 33  
Operating revenues – see Operating Revenues – Regulated Electric below     (12 )     (48 )
Regulated fuel for generation – see Regulated Fuel for Generation and Purchased Power below     13       41  
Recognition of a previously deferred corporate income tax recovery in Q1 2020 related to enactment of a lower corporate income tax rate in December 2018 at BLPC           7  
GBPC impairment charge in 2019     26       26  
Impact on earnings of sale of Emera Maine, net of tax     (7 )     (31 )
Other     3       (2 )
Contribution to consolidated net income – 2020   $ 7     $ 26  

 

In Q4 2019, the Company recognized a non-cash impairment charge, primarily related to goodwill, of $26 million USD due to a decrease in expected future cash flows resulting from the impacts of Hurricane Dorian storm recovery and changes in the anticipated long term regulated capital structure of GBPC. No impairment charge related to GBPC was recognized in 2020.

 

EMERA 2020 ANNUAL REPORT 37


 

MANAGEMENT’S DISCUSSION & ANALYSIS

 

Excluding the change in MTM, the 2019 impairment charges at GBPC and the sale of Emera Maine, Other Electric Utilities CAD’s contribution to consolidated net income increased $3 million quarter-over-quarter and decreased $2 million year-over-year. ECI’s contribution in Q4 2020 increased due to the continued recovery from Hurricane Dorian. ECI’s contribution for the year decreased due to lower commercial sales, partially offset by increased sales to residential customers due to the impact of the COVID-19 pandemic, and the impact from Hurricane Dorian at GBPC. The decrease was partially offset by recognition of a previously deferred corporate income tax recovery related to enactment of a lower corporate income tax rate in December 2018 at BLPC. The foreign exchange rate had minimal impact for the three months and year ended December 31, 2020.

 

Operating Revenues – Regulated Electric 

Operating revenues decreased $61 million to $79 million in Q4 2020, compared to $140 million in Q4 2019. For the year ended December 31, 2020, operating revenues decreased $207 million to $354 million compared to $561 million in 2019. Decreases in both periods were a result of the sale of Emera Maine in Q1 2020, lower fuel revenue at BLPC as a result of lower oil prices, lower commercial sales partially offset by increased sales to residential customers due to the impact of the COVID-19 pandemic, and the impacts of Hurricane Dorian at GBPC. Quarter-over-quarter, GBPC’s revenue was higher than Q4 2019 due to the continued recovery from the impacts of Hurricane Dorian in September 2019.

 

Electric revenues and sales volumes for ECI’s utilities are summarized in the following tables by customer class:

 

Q4 Electric Revenues

 

millions of USD              
      2020     2019  
Residential     $ 32     $ 35  
Commercial       40       49  
Industrial       5       6  
Other       2       3  
Total     $ 79     $ 93  

 

Q4 Electric Sales Volumes

 

GWh              
      2020     2019  
Residential       124       115  
Commercial       169       188  
Industrial       19       19  
Other       1       4  
Total       313       326  

Annual Electric Revenues

 

millions of USD              
      2020     2019  
Residential     $ 116     $ 125  
Commercial       161       198  
Industrial       21       21  
Other       12       15  
Total     $ 310     $ 359  

 

Annual Electric Sales Volumes

 

GWh              
      2020     2019  
Residential       493       463  
Commercial       650       742  
Industrial       80       78  
Other       17       15  
Total       1,240       1,298  


 

Regulated Fuel for Generation and Purchased Power

 

Regulated fuel for generation and purchased power decreased $23 million to $35 million in Q4 2020, compared to $58 million in Q4 2019. For the year ended December 31, 2020, regulated fuel for generation and purchased power decreased $71 million to $145 million compared to $216 million in 2019. The decreases in both periods were as a result of lower oil prices at BLPC. Production volumes and average fuel costs for ECI’s utilities are summarized in the following tables:

 

Q4 Production Volumes

 

GWh            
    2020     2019  
Oil     314       332  
Hydro     7       6  
Solar     4       4  
Purchased Power     12       9  
Total     337       351  

Annual Production Volumes

 

GWh            
    2020     2019  
Oil     1,247       1,338  
Hydro     19       20  
Solar     17       19  
Purchased Power     52       34  
Total     1,335       1,411  


 

38 EMERA 2020 ANNUAL REPORT


 

MANAGEMENT’S DISCUSSION & ANALYSIS

 

Q4 Average Fuel Costs

 

US dollars   2020     2019  
Dollars per MWh   $ 105     $ 135  

Annual Average Fuel Costs

 

US dollars   2020     2019  
Dollars per MWh   $ 102     $ 125  


Average fuel cost per MWh decreased in Q4 2020 and for the year ended December 31, 2020, compared to the same periods in 2019, due to lower oil prices.

 

Regulatory Recovery Mechanisms

 

BLPC 

BLPC is regulated by the FTC, an independent regulator. Rates are set to recover prudently incurred costs of providing electricity service to customers plus an appropriate return on capital invested. BLPC’s fuel costs flow through a fuel pass-through mechanism which provides opportunity to recover all prudently incurred fuel costs from customers in a timely manner. The FTC approves the calculation of the fuel charge, which is adjusted on a monthly basis.

 

GBPC 

GBPC is regulated by the GBPA. Rates are set to recover prudently incurred costs of providing electricity service to customers plus an appropriate return on rate base. GBPC’s fuel costs flow through a fuel pass-through mechanism which provides the opportunity to recover all prudently incurred fuel costs from customers in a timely manner.

 

GBPC maintains insurance for its generation facilities. As with most utilities, its transmission and distribution networks are self-insured. In 2019 Hurricane Dorian restoration costs for GBPC self-insured assets were $15 million USD. In January 2020, the GBPA approved the deferral of these costs through a regulated asset with recovery through rates over a five-year period. Recovery of the asset began January 1, 2021.

 

As a result of Hurricane Matthew in 2016, a regulatory asset was established to recover associated restoration costs. In addition, in December 2016, the GBPA approved that the all-in rate for electricity (fuel and base rates) would be held at 2016 levels over the five-year period from 2017 through 2021. This is achievable as the company’s fuel costs over this period are forecasted to decrease. Fuel costs are managed through a fuel hedging program which allows predictability of these costs. Any over-recovery of fuel costs during this period will be applied to the Hurricane Matthew regulatory asset, until such time as the asset is recovered. Should GBPC recover funds in excess of the Hurricane Matthew regulatory asset, the excess will be placed in a new storm reserve. If the Hurricane Matthew deferral is not fully recovered at the end of five years, GBPC will have the opportunity to request recovery from customers in future rates.

 

As a component of its regulatory agreement, GBPC has an Earnings Share Mechanism to allow for earnings on rate base to be deferred to a regulatory asset or liability at the rate of 50 per cent of amounts below a 7.34 per cent return on rate base and 50 per cent of amounts above 9.34 per cent return on rate base, respectively.

 

Domlec 

Domlec is regulated by the IRC. Rates are set to recover prudently incurred costs of providing electricity service to customers plus an appropriate return on rate base. Substantially all of Domlec fuel costs flow through a fuel pass-through mechanism which provides opportunity to recover prudently incurred fuel costs from customers in a timely manner.

 

EMERA 2020 ANNUAL REPORT 39


 

MANAGEMENT’S DISCUSSION & ANALYSIS

 

GAS UTILITIES AND INFRASTRUCTURE

 

All amounts are reported in USD, unless otherwise stated.

 

For the
millions of US dollars (except per share amounts)
  Three months ended
December 31
    Year ended
December 31
 
    2020     2019     2020     2019  
Operating revenues – regulated gas (1)   $ 234     $ 228     $ 780     $ 832  
Operating revenues – non-regulated     3       3       12       12  
Total operating revenue   $ 237     $ 231     $ 792     $ 844  
Regulated cost of natural gas   $ 80     $ 76     $ 221     $ 264  
Income from equity investments   $ 4     $ 3     $ 14     $ 17  
Contribution to consolidated net income   $ 35     $ 37     $ 122     $ 139  
Contribution to consolidated net income – CAD   $ 45     $ 51     $ 162     $ 183  
Contribution to consolidated earnings per common share – basic – CAD   $ 0.18     $ 0.21     $ 0.65     $ 0.76  
Net income weighted average foreign exchange rate – CAD/USD   $ 1.30     $ 1.32     $ 1.33     $ 1.33  
                                 
EBITDA   $ 81     $ 84     $ 294     $ 311  
EBITDA – CAD   $ 104     $ 114     $ 392     $ 413  

(1) Operating revenues – regulated gas includes $11 million of finance income from Brunswick Pipeline (2019 – $11 million) for the three months ended December 31, 2020 and $45 million (2019 – $45 million) for the year ended December 31, 2020, however, it is excluded from the gas revenues analysis below.

 

Gas Utilities and Infrastructure’s adjusted contribution is summarized in the following table:

 

For the
millions of US dollars
  Three months ended
December 31
    Year ended
December 31
 
    2020     2019     2020     2019  
PGS   $ 13     $ 12     $ 52     $ 54  
NMGC     12       15       30       46  
Other     10       10       40       39  
Contribution to adjusted consolidated net income   $ 35     $ 37     $ 122     $ 139  

 

Net Income 

 

Highlights of the net income changes are summarized in the following table:

 

For the
millions of US dollars
  Three months ended
December 31
    Year ended
December 31
 
Contribution to consolidated net income – 2019   $ 37     $ 139  
Increased (decreased) gas operating revenues – see Operating Revenues – Regulated Gas below     6       (43 )
Increased (decreased) cost of natural gas sold – see Regulated Cost of Natural Gas below     (4 )     43  
Recognition of tax benefits related to change in treatment of NOL carryforwards at NMGC in Q3 2019           (5 )
Decreased gas operating revenues as a result of recognition of tax reform benefits at NMGC in Q2 2019           (9 )
Other     (4 )     (3 )
Contribution to consolidated net income – 2020   $ 35     $ 122  

 

Gas Utilities and Infrastructure’s CAD contribution to consolidated net income decreased $6 million in Q4 2020, compared to Q4 2019. For the year ended December 31, 2020, Gas Utilities and Infrastructure’s CAD contribution to consolidated net income decreased $21 million compared to 2019. The decrease in both periods was the result of lower revenues due to warmer weather at NMGC, impacts of COVID-19 on commercial sales at PGS, and higher OM&G costs at PGS and NMGC. These impacts were partially offset by customer growth at PGS, increased AFUDC earnings at PGS, and higher return on investment in the cast iron and bare steel replacement rider at PGS. For the year ended December 31, 2020, the decrease was also due to the Q3 2019 recognition of tax benefits related to a change in treatment of NOL carryforwards and tax reform benefits recognized in Q2 2019 at NMGC.

 

The foreign exchange rate had minimal impact on CAD earnings in Q4 2020 and for the year ended December 31, 2020.

 

40 EMERA 2020 ANNUAL REPORT


 

MANAGEMENT’S DISCUSSION & ANALYSIS

 

Operating Revenues – Regulated Gas

 

Gas Utilities and Infrastructure’s operating revenues increased $6 million to $234 million in Q4 2020, compared to $228 million in Q4 2019 due to higher clause related revenues and customer growth at PGS partially offset by lower off-system sales at PGS and lower commercial sales related to the COVID-19 pandemic at PGS.

 

For the year ended December 31, 2020, operating revenues decreased $52 million to $780 million, compared to $832 million in 2019 due to lower clause-related revenues, lower off-system sales at PGS, warmer weather at NMGC and lower commercial sales related to the COVID-19 pandemic at PGS. This decrease was partially offset by customer growth at PGS. For the year ended December 31, 2020, the decrease was also due to NMGC’s recognition of tax reform benefits in Q2 2019.

 

Gas revenues and sales volumes are summarized in the following tables by customer class:

 

Q4 Gas Revenues

 

millions of US dollars            
    2020     2019  
Residential   $ 122     $ 109  
Commercial     63       63  
Industrial (1)     11       9  
Other (2)     27       36  
Total (3)   $ 223     $ 217  

(1) Industrial includes sales to power generation customers.

(2) Other includes off-system sales to other utilities and various other items.
(3) Excludes $11 million of finance income from Brunswick Pipeline (2019 – $11 million).

 

Q4 Gas Volumes

 

Therms (millions)            
    2020     2019  
Residential     132       138  
Commercial     220       225  
Industrial     388       376  
Other     59       88  
Total     799       827  

Annual Gas Revenues

 

millions of US dollars            
    2020     2019  
Residential   $ 372     $ 379  
Commercial     207       225  
Industrial (1)     41       37  
Other (2)     115       146  
Total (3)   $ 735     $ 787  

(1) Industrial includes sales to power generation customers.

(2) Other includes off-system sales to other utilities and various other items.
(3) Excludes $45 million of finance income from Brunswick Pipeline (2019 – $45 million).

 

Annual Gas Volumes

 

Therms (millions)            
    2020     2019  
Residential     405       413  
Commercial     767       830  
Industrial     1,586       1,482  
Other     298       317  
Total     3,056       3,042  


 

Regulated Cost of Natural Gas

 

PGS and NMGC purchase gas from various suppliers depending on the needs of their customers. In Florida, gas is delivered to the PGS distribution system through three interstate pipelines on which PGS has firm transportation capacity for delivery by PGS to its customers. NMGC’s natural gas is transported on major interstate pipelines and NMGC’s intrastate transmission system to customers.

 

In Florida, natural gas service is unbundled for non-residential customers and residential customers who use more than 1,999 therms annually and elect the option. In New Mexico, NMGC is required, if requested, to provide transportation-only services for all customer classes. Because the commodity portion of bundled sales is included in operating revenues, at the cost of the gas on a pass-through basis, there is no net earnings effect when a customer shifts to transportation-only sales.

 

Regulated cost of natural gas increased $4 million to $80 million in Q4 2020, compared to $76 million in Q4 2019 due to higher commodity costs at PGS and NMGC.

 

For the year ended December 31, 2020, regulated cost of natural gas decreased $43 million to $221 million in Q4 2020, compared to $264 million in 2019. The decrease was due to lower commodity costs at PGS and NMGC in the first three quarters of the year, lower system supply to customers and lower volume of off-system sales at PGS.

 

EMERA 2020 ANNUAL REPORT 41


 

MANAGEMENT’S DISCUSSION & ANALYSIS

 

Gas sales by type are summarized in the following table:

 

Q4 Gas Volumes by Type

 

Therms (millions)            
    2020     2019  
System supply     197       235  
Transportation     602       592  
Total     799       827  

Annual Gas Volumes by Type

 

Therms (millions)            
    2020     2019  
System supply     690       754  
Transportation     2,366       2,288  
Total     3,056       3,042  


 

Regulatory Recovery Mechanisms

 

PGS 

 

PGS is regulated by the FPSC. The FPSC sets rates at a level that allows utilities such as PGS to collect total revenues or revenue requirements equal to their cost of providing service, plus an appropriate return on invested capital.

 

Other Cost Recovery 

 

Fuel Recovery Clause 

 

PGS recovers the costs it pays for gas supply and interstate transportation for system supply through its purchased gas adjustment (“PGA”) clause. This clause is designed to recover actual costs incurred by PGS for purchased gas, gas storage services, interstate pipeline capacity, and other related items associated with the purchase, distribution, and sale of natural gas to its customers. These charges may be adjusted monthly subject to a cap approved annually by the FPSC.

 

Other Cost Recovery Clauses 

 

The FPSC annually approves cost-recovery rates for conservation costs including a return on capital invested incurred in developing and implementing energy conservation programs. PGS has a Cast Iron/Bare Steel Pipe Replacement clause to recover the cost of accelerating the replacement of cast iron and bare steel distribution lines in the PGS system. In February 2017, the FPSC approved expansion of the Cast Iron/Bare Steel clause to allow recovery of accelerated replacement of certain obsolete plastic pipe. PGS estimates that all cast iron and bare steel pipe will be removed from its system by 2022, with replacement of obsolete plastic pipe continuing until 2028 under the rider.

 

NMGC 

 

NMGC is subject to regulation by the NMPRC. The NMPRC sets rates at a level that allows NMGC to collect total revenues equal to its cost of providing service, plus an appropriate return on invested capital.

 

Other Cost Recovery 

 

Fuel Recovery Clause  

 

NMGC recovers gas supply costs through a purchased gas adjustment clause (“PGAC”). This clause recovers NMGC’s actual costs for purchased gas, gas storage services, interstate pipeline capacity, and other related items associated with the purchase, distribution, and sale of natural gas to its customers.

 

On a monthly basis, NMGC can adjust charges based on next month’s expected cost of gas and any prior month under-recovery or over-recovery. NMGC must file a PGAC Continuation Filing with the NMPRC every four years to establish that continued use of the PGAC is reasonable and necessary. In December 2020, NMGC received approval of its PGAC Continuation Filing for the four-year period ending December 2024.

 

Weather Normalization Mechanism  

 

In July 2019, the NMPRC approved changes to the company’s rate design to include a Weather Normalization Mechanism. This clause is designed to lower the variability of weather impacts during the October through April heating seasons. The Weather Normalization Mechanism will allow customer rates and company revenue to be more predictable by partially removing the impact of warmer than usual or colder than usual weather. Weather-related revenue increases or decreases experienced from October to April will be adjusted annually in October of the following heating season.

 

42 EMERA 2020 ANNUAL REPORT


 

MANAGEMENT’S DISCUSSION & ANALYSIS

 

IMP Regulatory Asset

 

A portion of NMGC’s annual spend on infrastructure is for integrity management programs (“IMP”), or the replacement and update of legacy systems. These programs are driven both by NMGC integrity management plans and federal and state mandates. In December 2020, NMGC received approval through its rate case to defer costs through an IMP regulatory asset for certain of its IMP capital investments occurring between January 1, 2022 and December 31, 2023 and will seek recovery for the regulatory asset in its next rate case filing.

 

OTHER

 

For the
millions of Canadian dollars (except per share amounts)
  Three months ended
December 31
  Year ended
December 31
 
      2020     2019     2020     2019  
Marketing and trading margin (1) (2)   $ 22   $ 28   $ 38   $ 31  
Electricity and capacity sales (3)     4     2     16     118  
Other non-regulated operating revenue     8     1     21     31  
Total operating revenues – non-regulated   $ 34   $ 31   $ 75   $ 180  
Intercompany revenue (4)     3     3     13     20  
Non-regulated fuel for generation and purchased power (5)     3     2     15     68  
Income from equity investments     7     7     24     32  
Interest expense, net     71     81     301     337  
Adjusted contribution to consolidated net income (loss)   $ (23 ) $ (58 ) $ (252 ) $ (286 )
Gain on sale, net of tax and transaction costs     -     -     309     -  
Impairment charges, net of tax     -     -     (26 )   -  
After-tax derivative MTM gain (loss)   $ 83   $ 81   $ (12 ) $ 73  
Contribution to consolidated net income (loss)   $ 60   $ 23   $ 19   $ (213 )
Adjusted contribution to consolidated earnings per common share – basic   $ (0.09 ) $ (0.24 ) $ (1.02 ) $ (1.19 )
Contribution to consolidated earnings per common share – basic   $ 0.24   $ 0.09   $ 0.08   $ (0.89 )
Adjusted EBITDA   $ 50   $ 2   $ 25   $ 9  
(1) Marketing and trading margin represents EES’s purchases and sales of natural gas and electricity, pipeline and storage capacity costs and energy asset management services’ revenues.

(2) Marketing and trading margin excludes a pre-tax MTM gain of $109 million in Q4 2020 (2019 – $119 million gain) and a loss of $46 million for the year ended December 31,2020 (2019 – $100 million gain).

(3) Electricity and capacity sales exclude a pre-tax MTM of nil in Q4 2020 (2019 – nil) and nil for the year ended December 31, 2020 (2019 – $2 million gain).

(4) Intercompany revenue consists of interest from Brunswick Pipeline and M&NP.

(5) Non-regulated fuel for generation and purchased power excludes a pre-tax MTM of nil in Q4 2020 (2019 – $1 million loss) and a $3 million gain for the year ended December 31, 2020 (2019 – $2 million loss).

 

Other’s adjusted contribution to consolidated net income is summarized in the following table:

 

For the
millions of Canadian dollars
  Three months ended
December 31
  Year ended
December 31
 
      2020     2019     2020     2019  
Emera Energy   $ 15   $ 18   $ 17   $ 37  
Corporate     (37 )   (75 )   (267 )   (322 )
Other     (1 )   (1 )   (2 )   (1 )
Adjusted contribution to consolidated net income (loss)   $ (23 ) $ (58 ) $ (252 ) $ (286 )

 

EMERA 2020 ANNUAL REPORT 43


 

MANAGEMENT’S DISCUSSION & ANALYSIS

 

Mark-to-Market Adjustments
Emera Energy’s “Marketing and trading margin”, “Electricity and capacity sales”, “Non-regulated fuel for generation and purchased power”, “Income from equity investments” and “Income tax expense (recovery)” are affected by MTM adjustments. Management believes excluding the effect of MTM valuations, and changes thereto, from income until settlement better matches the financial effect of these contracts with the underlying cash flows. Variance explanations of the MTM changes for this quarter and for the year are explained in the chart below.

 

Emera Energy has a number of asset management agreements (“AMA”) with counterparties, including local gas distribution utilities, power utilities and natural gas producers in North America. The AMAs involve Emera Energy buying or selling gas for a specific term, and the corresponding release of the counterparties’ gas transportation/storage capacity to Emera Energy. MTM adjustments on these AMAs arise on the price differential between the point where gas is sourced and where it is delivered. At inception, the MTM adjustment is offset fully by the value of the corresponding gas transportation asset, which is amortized over the term of the AMA contract.

 

Subsequent changes in gas price differentials, to the extent they are not offset by the accounting amortization of the gas transportation asset, will result in MTM gains or losses recorded in income. MTM adjustments may be substantial during the term of the contract, especially in the winter months of a contract when delivered volumes and market pricing are usually at peak levels. As a contract is realized, and volumes reduce, MTM volatility is expected to decrease. Ultimately, the gas transportation asset and the MTM adjustment reduce to zero at the end of the contract term. As the business grows, and AMA volumes increase, MTM volatility resulting in gains and losses may also increase.

 

In 2020 Emera Corporate entered into foreign exchange forwards to manage the cash flow risk of forecasted USD cash inflows. Fluctuations in the foreign exchange rate result in MTM gains or losses recorded in income.

 

Net Income
Highlights of the net income changes are summarized in the following table:

 

For the
millions of Canadian dollars
  Three months ended
December 31
  Year ended
December 31
 
Contribution to consolidated net income (loss) – 2019   $ 23   $ (213 )
Increased (decreased) marketing and trading margin – see Emera Energy below     (6 )   7  
Decreased other income due to 2019 gain on sale of property in Florida, net of tax     -     (10 )
Decreased interest expense primarily due to lower interest rates and repayment of corporate long-term debt     10     30  
Revaluation of net deferred income tax assets resulting from the enactment of a lower Nova Scotia provincial corporate income tax rate in Q1 2020, including $2 million recovery related to MTM     -     (11 )
Timing of preferred stock dividends issued     (11 )   -  
TGH award, net of tax and legal costs     36     36  
Impact of sale of NEGG and Bayside Power, net of tax     1     (21 )
Impairment charges recognized on certain other assets     -     (26 )
Gain on sale of Emera Maine, net of tax and transaction costs     -     309  
Changes in MTM gains and losses in both periods are due to changes in existing hedging positions and changes in amortization on gas transportation assets at Emera Energy, partially offset by foreign exchange gains on cash flow hedges     2     (87 )
Decreased income from Bear Swamp equity investment due to reduced energy deliveries resulting from a third-party transmission line outage, lower New England capacity prices and less favourable energy conditions     -     (8 )
2019 Corporate share of the unrecoverable loss at GBPC facilities     6     15  
Other     (1 )   (2 )
Contribution to consolidated net income (loss) – 2020   $ 60   $ 19  

 

44 EMERA 2020 ANNUAL REPORT


 

MANAGEMENT’S DISCUSSION & ANALYSIS

 

Excluding the change in MTM, gain on sale of Emera Maine and impairment charges recognized on certain other assets, Other’s contribution to consolidated net income increased by $35 million in Q4 2020, compared to Q4 2019. For the year ended December 31, 2020, Other’s contribution to consolidated net income increased $34 million, compared to the same period in 2019. The increase in both periods was primarily due to the TGH award, lower corporate interest and the 2019 recognition of the Corporate share of the unrecoverable loss on GBPC facilities. The quarter-over-quarter increase was partially offset by timing of preferred stock dividends and decreased marketing and trading margin. Year-over-year increase was also due to higher marketing and trading margin partially offset by the impact of the sale of NEGG and Bayside, revaluation of net deferred income tax assets resulting from the Q1 2020 enactment of a lower Nova Scotia provincial corporate income tax rate, and the 2019 sale of property in Florida.

 

Emera Energy
EES derives revenue and earnings from the wholesale marketing and trading of natural gas, electricity and other energy-related commodities and derivatives within the Company’s risk tolerances, including those related to value-at-risk (“VaR”) and credit exposure. EES purchases and sells physical natural gas and electricity, the related transportation and transmission capacity rights, and provides energy asset management services. The primary market area for the natural gas and power marketing and trading business is northeastern North America, including the Marcellus and Utica shale supply areas. EES also participates in the Florida, US Gulf Coast and Midwest/Central Canadian natural gas markets. Its counterparties include electric and gas utilities, natural gas producers, electricity generators and other marketing and trading entities. EES operates in a competitive environment, and the business relies on knowledge of the region’s energy markets, understanding of pipeline and transmission infrastructure, a network of counterparty relationships and a focus on customer service. EES manages its commodity risk by limiting open positions, utilizing financial products to hedge purchases and sales, and investing in transportation capacity rights to enable movement across its portfolio.

 

Marketing and Trading
Marketing and trading margin decreased $6 million in Q4 2020, compared to Q4 2019 primarily due to lower hedged margin net of fixed commitments for gas transportation and storage.

 

For the year ended December 31, 2020, marketing and trading margin increased $7 million compared to the same period in 2019. This increase was primarily due to increased hedged margin net of fixed commitments for gas transportation storage assets in the summer months, partially offset by less favourable winter market conditions, specifically warmer than normal Q1 winter weather and lower natural gas prices in 2020 compared to 2019.

 

LIQUIDITY AND CAPITAL RESOURCES

 

The Company generates internally sourced cash from its various regulated and non-regulated energy investments. Utility customer bases are diversified by both sales volumes and revenues among customer classes. Emera’s non-regulated businesses provide diverse revenue streams and counterparties to the business. Circumstances that could affect the Company’s ability to generate cash include general economic downturns in markets served by Emera, the loss of one or more large customers, regulatory decisions affecting customer rates and the recovery of regulatory assets and changes in environmental legislation. Emera’s subsidiaries are generally in a financial position to contribute cash dividends to Emera provided they do not breach their debt covenants, where applicable, after giving effect to the dividend payment, and maintain their credit metrics.

 

During the year ended December 31, 2020, the effects of the ongoing COVID-19 pandemic including the resulting government measures to address this pandemic have resulted in economic slowdowns in all markets served by Emera. The pace and strength of economic recovery is uncertain and may vary among jurisdictions.

 

EMERA 2020 ANNUAL REPORT 45


 

MANAGEMENT’S DISCUSSION & ANALYSIS

 

The pandemic has generally resulted in lower load and higher operating costs than what otherwise would have been experienced at the Company’s utilities. Some of Emera’s utilities have been impacted more than others. However, on a consolidated basis, these unfavourable impacts have not had a material impact to consolidated net earnings. Refer to the “Business Overview and Outlook – COVID-19 Pandemic” section of this document for further discussion. The ongoing economic impact of the pandemic may affect customers’ ability to pay. As a result of the temporary suspension of disconnections, the Company’s utilities experienced an increase in the aging of customer receivables. This trend has begun to reverse as normal disconnection processes resume. There have been no significant customer defaults as a result of bankruptcies with many customer accounts secured by deposits. As of December 31, 2020, adjustments to the allowance for credit losses have increased but have not had a material impact on earnings. The full impact of potential credit losses due to customer non-payment is not known at this time. The utilities are continuing to monitor customer accounts and are working with customers on payment arrangements.

 

The extent of the future impact of COVID-19 on the Company’s operating cash flow cannot be predicted at this time and will depend on future developments, including the duration and severity of the pandemic, timing and effectiveness of vaccinations, further potential government actions and future economic activity and energy usage. The Company currently expects to continue to have adequate liquidity given its cash position, existing bank facilities, and access to capital, but will continue to monitor the impact of COVID-19 on future cash flows.

 

Emera’s future liquidity and capital needs will be predominately for working capital requirements, ongoing rate base investment, business acquisitions, greenfield development, dividends and debt servicing. Emera has a $7.4 billion capital investment plan over the 2021-to-2023 period and the potential for additional capital opportunities of $1.2 billion over the same period. This plan includes significant rate base investments across the portfolio in renewable and cleaner generation, infrastructure modernization and customer-focused technologies. Capital expenditures at the regulated utilities are subject to regulatory approval. The extent of the future impact of COVID-19 on the profile of the Company’s capital plan cannot be predicted at this time due to reasons discussed earlier. The Company has flexibility with respect to its capital investment plan and will continue to monitor current events and related impacts of COVID-19.

 

Emera plans to use cash from operations and debt raised at the utilities to support normal operations, repayment of existing debt and capital requirements. Debt raised at certain of the Company’s utilities is subject to applicable regulatory approvals. Equity requirements in support of the Company’s capital investment plan will predominantly be funded in the equity capital markets through the dividend reinvestment plan and the issuance of common and preferred equity. The Company’s future access to capital may be impacted by possible COVID-19 related market disruptions. Refer to the “Risk Management and Financial Instruments” section of this document.

 

Emera has credit facilities with varying maturities that cumulatively provide $3.7 billion of credit, with approximately $1.7 billion undrawn and available at December 31, 2020. The Company was holding a cash balance of $254 million at December 31, 2020. Refer to the “Debt Management” section below for further details. Refer to notes 23 and 25 in the consolidated financial statements for additional information regarding the credit facilities.

 

CONSOLIDATED CASH FLOW HIGHLIGHTS

Significant changes in the statements of cash flows between the years ended December 31, 2020 and 2019 include:

 

millions of Canadian dollars   2020   2019   $ Change  
Cash, cash equivalents and restricted cash, beginning of period   $ 274   $ 372   $ (98 )
Provided by (used in):                    
Operating cash flow before changes in working capital     1,420     1,598     (178 )
Change in working capital     217     (73 )   290  
Operating activities     1,637     1,525     112  
Investing activities     (1,224 )   (1,617 )   393  
Financing activities     (372 )   14     (386 )
Effect of exchange rate changes on cash and cash equivalents     (61 )   (20 )   (41 )
Cash, cash equivalents, restricted cash and cash included in assets held for sale, end of period   $ 254   $ 274   $ (20 )

 

46 EMERA 2020 ANNUAL REPORT


 

MANAGEMENT’S DISCUSSION & ANALYSIS

 

Cash Flow from Operating Activities
Net cash provided by operating activities increased $112 million to $1,637 million for the year ended December 31, 2020, compared to $1,525 million in 2019.

 

Cash from operations before changes in working capital decreased $178 million in 2020. The decrease was primarily due to the impact of the sale of Emera Maine in Q1 2020, lower earnings at NSPI, and higher under-recovery of clause related costs at Tampa Electric.

 

Changes in working capital increased operating cash flows by $290 million. The increase was due to favourable changes in cash collateral positions on derivative instruments at NSPI, decreased investment in fuel inventory at NSPI, and the receipt in 2020 of a 2019 income tax refund at NSPI. This was partially offset by timing of accounts payable payments at Tampa Electric and NMGC.

 

Cash Flow Used in Investing Activities
Net cash used in investing activities decreased $393 million to $1,224 million for the year ended December 31, 2020, compared to $1,617 million in 2019. In 2020, Emera received proceeds of $1.4 billion on the sale of Emera Maine, compared to proceeds of $875 million on dispositions in 2019, primarily from the sale of the NEGG and Bayside facilities. This increase in proceeds was partially offset by an increase in capital expenditures in 2020.

 

Capital expenditures for the year ended December 31, 2020, including AFUDC, were $2,668 million compared to $2,516 million in 2019. Details of the 2020 capital spend by segment are shown below:

 

$1,415 million – Florida Electric Utility (2019 – $1,414 million);

$342 million – Canadian Electric Utilities (2019 – $389 million);

$149 million – Other Electric Utilities (2019 – $200 million);

$758 million – Gas Utilities and Infrastructure (2019 – $450 million); and

$4 million – Other (2019 – $63 million).

 

Cash Flow from Financing Activities
Net cash used in financing activities increased $386 million to $372 million for the year ended December 31, 2020, compared to cash provided by financing activities of $14 million in 2019. The increase was due to 2019 proceeds from Emera’s non-revolving credit facilities, net repayment of debt at TECO Finance, higher net repayments of Emera’s committed credit facilities, and lower proceeds from the issuance of long-term debt at NSPI. These were partially offset by a 2019 repayment of corporate long-term debt, proceeds from short-term debt at Tampa Electric and PGS, lower net repayments of NSPI’s committed credit facilities and the 2019 retirement of long-term debt at NSPI.

 

WORKING CAPITAL
As at December 31, 2020, Emera’s cash and cash equivalents were $220 million (2019 – $222 million) and Emera’s investment in non-cash working capital was $266 million (2019 – $566 million). Of the cash and cash equivalents held at December 31, 2020, $197 million was held by Emera’s foreign subsidiaries (2019 – $208 million). A portion of these funds are invested in countries that have certain exchange controls, approvals, and processes for repatriation. Such funds are available to fund local operating and capital requirements unless repatriated.

 

EMERA 2020 ANNUAL REPORT 47


 

MANAGEMENT’S DISCUSSION & ANALYSIS

 

CONTRACTUAL OBLIGATIONS

 

As at December 31, 2020, contractual commitments for each of the next five years and in aggregate thereafter consisted of the following:

 

millions of Canadian dollars   2021   2022   2023   2024   2025   Thereafter   Total  
Long-term debt principal   $ 1,382   $ 407   $ 809   $ 820   $ 226   $ 10,182   $ 13,826  
Interest payment obligations (1)     585     552     531     516     497     6,364     9,045  
Purchased power (2)     231     218     216     218     224     2,242     3,349  
Transportation (3)     518     393     339     306     282     2,704     4,542  
Pension and post-retirement obligations (4)     30     37     31     32     31     184     345  
Capital projects     394     98     76                 568  
Fuel, gas supply and storage     494     91     6     1             592  
Asset retirement obligations     21     2     2     7     2     391     425  
Long-term service agreements (5)     43     41     36     33     34     92     279  
Equity investment commitments (6)         240                     240  
Leases and other (7)     16     17     16     15     8     118     190  
Demand side management     40     45                     85  
Long-term payable     5     5     5                 15  
    $ 3,759   $ 2,146   $ 2,067   $ 1,948   $ 1,304   $ 22,277   $ 33,501  
(1) Future interest payments are calculated based on the assumption that all debt is outstanding until maturity. For debt instruments with variable rates, interest is calculated for all future periods using the rates in effect at December 31, 2020, including any expected required payment under associated swap agreements.

(2) Annual requirement to purchase electricity production from IPP’s or other utilities over varying contract lengths.

(3) Purchasing commitments for transportation of fuel and transportation capacity on various pipelines. Includes a commitment of $149 million related to a gas transportation contract between PGS and SeaCoast through 2040.

(4) The estimated contractual obligation is calculated as the current legislatively required contributions to the registered funded pension plans (excluding the possibility of wind-up), plus the estimated costs of further benefit accruals contracted under NSPI’s Collective Bargaining Agreement and estimated benefit payments related to other unfunded benefit plans.

(5) Maintenance of certain generating equipment, services related to a generation facility and wind operating agreements, outsourced management of computer and communication infrastructure and vegetation management.

(6) Emera has a commitment to make equity contributions to the Labrador Island Link Limited Partnership.

(7) Includes operating lease agreements for buildings, land, telecommunications services and rail cars, transmission rights and investment commitments.

 

On March 17, 2020, Nalcor announced that it had paused construction activities at the Muskrat Falls site in response to the COVID-19 pandemic. As a result of the effects of COVID-19 on project execution, Nalcor declared force majeure under various project contracts, including formal notification to NSPML. Nalcor achieved first power on the first of four generators at Muskrat Falls on September 22, 2020 and continues to work toward completing project commissioning in 2021.

 

NSPML expects to file a final cost assessment with the UARB upon commencement of the NS Block of energy from Muskrat Falls, which is anticipated to take place in 2021. On December 16, 2020, the UARB approved NSPML’s 2021 interim assessment for recovery from NSPI of Maritime Link costs of approximately $172 million subject to a holdback of $10 million with similar terms as previously approved by the UARB and a potential long-term deferral of up to $23 million in depreciation expense dependent upon the timing of commencement of the NS Block.

 

NSPI has a contractual obligation to pay NSPML for the use of the Maritime Link over approximately 38 years from its January 15, 2018 in-service date. As part of NSPI’s 2020-2022 fuel stability plan, rates have been set to include the $145 million approved for 2020 and amounts of $164 million and $162 million for 2021 and 2022, respectively. On December 16, 2020, the UARB approved the 2021 interim cost assessment of approximately $172 million. Any difference between the amounts included in the NSPI fuel stability plan and those approved by the UARB through the NSPML interim assessment application will be addressed through the FAM. The timing and amounts payable to NSPML for the remainder of the 38-year commitment period are dependent on regulatory filings with the UARB.

 

Once Muskrat Falls and LIL have achieved full power, the commercial agreements between Emera and Nalcor require true ups to finalize the respective investment obligations of the parties relating to the Maritime Link and LIL.

 

48 EMERA 2020 ANNUAL REPORT


 

MANAGEMENT’S DISCUSSION & ANALYSIS

 

Emera has committed to obtain certain transmission rights for Nalcor Energy, if requested, to enable them to transmit energy which is not otherwise used in Newfoundland or Nova Scotia. This energy could be transmitted from Nova Scotia to New England energy markets beginning at first commercial power of the Muskrat Falls hydroelectric generating facility and related transmission assets when Nalcor commences delivery of the NS Block, and continuing for 50 years. As transmission rights are contracted, the obligations are included within “Leases and other” in the above table.

 

FORECASTED GROSS CONSOLIDATED CAPITAL EXPENDITURES

 

2021 forecasted gross consolidated capital expenditures are as follows:

 

millions of Canadian dollars   Florida
Electric Utility
    Canadian
Electric
Utilities
    Other Electric
Utilities
    Gas
Utilities and
Infrastructure
    Other     Total  
Generation   $ 617     $ 150     $ 55     $     $     $ 822  
New renewable generation     176             96                   272  
Transmission     73       60       2                   135  
Distribution     448       100       44                   592  
Gas transmission and distribution                       509             509  
Facilities, equipment, vehicles, and other     152       60       16       36       2       266  
    $ 1,466     $ 370     $ 213     $ 545     $ 2     $ 2,596  

 

DEBT MANAGEMENT

 

In addition to funds generated from operations, Emera and its subsidiaries have, in aggregate, access to approximately $3.7 billion committed syndicated revolving bank lines of credit in either CAD or USD per the table below.

 

millions of dollars   Maturity     Revolving
Credit Facilities
    Utilized     Undrawn
and Available
 
Emera – Unsecured committed revolving credit facility   June 2024     $ 900     $ 286     $ 614  
TEC – in USD – Unsecured committed revolving credit facility (1)   March 2023       800       346       454  
NSPI – Unsecured committed revolving credit facility   October 2024       600       300       300  
Emera – Unsecured non-revolving facility   December 2021       400       400        
TECO Finance – in USD – Unsecured committed revolving credit facility   March 2023       400       161       239  
TEC – in USD – Unsecured non-revolving facility (1)   February 2021       300       300        
TEC – in USD – Accounts receivable collateralized borrowing facility (1)   March 2021       150       130       20  
NMGC – in USD – Unsecured committed revolving credit facility   March 2023       125       19       106  
Other – in USD – Unsecured committed revolving credit facilities   Various       35       20       15  

(1) These facilities are available for use by Tampa Electric and PGS. At December 31, 2020, Tampa Electric had utilized $562 million USD and PGS had utilized $214 million USD of the facilities.

 

Emera and its subsidiaries have certain financial and other covenants associated with their debt and credit facilities. Covenants are tested regularly, and the Company is in compliance with covenant requirements as at December 31, 2020. Emera’s significant covenant is listed below:

 

    Financial Covenant   Requirement     As at
December 31, 2020
 
Emera                
Syndicated credit facilities   Debt to capital ratio   Less than or equal to 0.70 to 1     0.56 : 1  

 

EMERA 2020 ANNUAL REPORT 49


 

MANAGEMENT’S DISCUSSION & ANALYSIS

 

Recent significant financing activities for Emera and its subsidiaries are discussed below by segment:

 

Florida Electric Utilities 

On February 6, 2020, TEC entered into a $300 million USD non-revolving credit agreement with a maturity date of February 4, 2021. The credit agreement contains customary representations and warranties, events of default, financial and other covenants and bears interest on either the London interbank deposit rate (“LIBOR”), prime rate or the federal funds rate, plus a margin. On January 29, 2021, TEC extended the maturity date of the agreement to April 29, 2021 with no other changes in terms.

 

On December 18, 2020, TEC amended and restated its bank credit facility. The amendment extended the maturity date of the credit facility from March 22, 2022 to March 22, 2023 and increased the amount of the commitment by the lenders to $800 million USD from $400 million USD. The credit facility bears interest based on either the LIBOR, the Wells Fargo Bank’s prime rate, or the federal funds rate, plus a margin. The amended facility now includes a $80 million USD letter of credit facility. There were no other significant changes in commercial terms from the prior agreement.

 

Canadian Electric Utilities 

On April 24, 2020, NSPI completed a $300 million 30-year unsecured notes issuance. The notes bear interest at a rate of 3.31 per cent and have a maturity date of April 25, 2050.

 

Other Electric Utilities 

On May 20, 2020, GBPC entered into a $22 million USD non-revolving term loan with a maturity date of May 20, 2025. The loan bears interest at a rate of 90-day LIBOR plus a margin. On May 22, 2020, proceeds from this loan were used to repay $22 million USD senior notes upon maturity.

 

On May 20, 2020, GBPC entered into a $15 million BSD ($15 million USD) non-revolving term loan with a maturity date of May 20, 2025. The loan bears interest at a rate of 4.00 per cent.

 

At December 31, 2020, BLPC had drawn $77 million BBD ($38 million USD) against a $110 million BBD ($55 million USD) non- revolving term loan. The loan bears interest at a rate of 2.05 per cent and has a 5-year term.

 

Gas Utilities and Infrastructure 

On February 5, 2021, NMGC completed an issuance of $220 million USD senior notes. The issuance included $70 million USD senior notes that bear interest at a rate of 2.26 per cent with a maturity date of February 5, 2031, $65 million USD senior notes that bear interest at a rate of 2.51 per cent and with a maturity date of February 5, 2036, and $85 million USD senior notes that bear interest at a rate of 3.34 per cent with a maturity date of February 5, 2051. Proceeds from this issuance were used to repay a $200 million USD note, due in 2021 and for general corporate purposes. These notes were classified as long-term debt at December 31, 2020.

 

On December 18, 2020, NMGC amended and restated its $125 million USD bank credit facility. The amendment extended the maturity date of the credit facility from March 22, 2022 to March 22, 2023. The credit facility bears interest based on either the LIBOR, JP Morgan Chase Bank’s prime rate, or the federal funds rate, plus a margin. The amended facility now includes a $30 million USD letter of credit facility. There were no other significant changes in commercial terms from the prior agreement.

 

Other 

On February 28, 2020, TECO Finance extended the maturity date of its $500 million USD credit facility from March 5, 2020 to July 3, 2020. There were no other significant changes in commercial terms from the prior agreement. Using funds from the sale of Emera Maine, on April 3, 2020, TECO Finance repaid $200 million USD of the term loan and the remaining $300 million USD was repaid on June 30, 2020.

 

On March 13, 2020, TECO Finance repaid a $300 million USD note upon maturity. The note was repaid using existing credit facilities.

 

On December 1, 2020, Emera extended the maturity date of its $400 million non-revolving term loan from December 15, 2020 to December 16, 2021. There were no other significant changes in commercial terms from the prior agreement.

 

On December 18, 2020, TECO Finance amended and restated its $400 million USD bank credit facility. The amendment extended the maturity date of the credit facility from March 22, 2022 to March 22, 2023. The credit facility bears interest based on either the LIBOR, JP Morgan Chase Bank’s prime rate, or the federal funds rate, plus a margin. The facility now includes a $50 million USD letter of credit facility. There were no other significant changes in commercial terms from the prior agreement.

 

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MANAGEMENT’S DISCUSSION & ANALYSIS

 

CREDIT RATINGS

 

Emera and its subsidiaries have been assigned the following senior unsecured debt ratings:

 

    Fitch   S&P     Moody’s     DBRS
Emera Inc.   BBB (Stable)   BBB- (Stable)     Baa3 (Stable)     N/A
TECO Energy/TECO Finance   N/A   BBB- (Stable)     Baa1 (Positive)     N/A
TEC   A (Stable)   BBB+ (Stable)     A3 (Positive)     N/A
NMGC   BBB+ (Stable)   N/A     N/A     N/A
NSPI   N/A   BBB+ (Stable)     N/A     A (low) (Stable)

 

On December 21, 2020, Moody’s Investor Services upgraded its senior unsecured bank credit rating on TECO Energy to Baa1 from Baa2. Moody’s also affirmed TEC’s A3 senior unsecured rating. The rating outlook remains positive.

 

On July 8, 2020, Fitch Ratings assigned a first-time long-term issuer default rating of BBB+ to NMGC. The rating outlook is stable.

 

On March 24, 2020, S&P changed its issuer rating for Emera and TECO to BBB from BBB+ and at the same time changed the outlook on both to stable from negative. S&P also affirmed its BBB+ issuer ratings for TEC and NSPI and changed the outlook on both to stable from negative.

 

SHARE CAPITAL

 

Emera 

As at December 31, 2020, Emera had 251.43 million (2019 – 242.48 million) common shares issued and outstanding. For the year ended December 31, 2020, 8.95 million common shares were issued (2019 – 8.36 million) for net proceeds of $489 million (2019 – $400 million).

 

As at December 31, 2020, Emera had 41 million preferred shares issued and outstanding (2019 – 41 million).

 

PENSION FUNDING

 

For funding purposes, Emera determines required contributions to its largest defined benefit pension plans based on smoothed asset values. This reduces volatility in the cash funding requirement as the impact of investment gains and losses are recognized over a three-year period. The cash required in 2021 for defined benefit pension plans is expected to be $41 million (2020 – $41 million). All pension plan contributions are tax deductible and will be funded with cash from operations.

 

Emera’s defined benefit pension plans employ a long-term strategic approach with respect to asset allocation, real return and risk. The underlying objective is to earn an appropriate return, given the Company’s goal of preserving capital within an acceptable level of risk for the pension fund investments.

 

To achieve the overall long-term asset allocation, pension assets are managed by external investment managers per the pension plan’s investment policy and governance framework. The asset allocation includes investments in the assets of Canadian and global equities, domestic and global bonds and short-term investments. Emera reviews investment manager performance on a regular basis and adjusts the plans’ asset mixes as needed in accordance with the pension plans’ investment policy.

 

Emera’s projected contributions to defined contribution pension plans, are $44 million for 2021 (2020 – $45 million).

 

DEFINED BENEFIT PENSION PLAN SUMMARY

 

millions of Canadian dollars                              
Plans by region   TECO Energy     NSPI     Maine (1)     Caribbean     Total  
Assets as at December 31, 2020   $ 1,150     $ 1,445     $     $ 10     $ 2,605  
Accounting obligation at December 31, 2020     1,168       1,576             15       2,759  
Accounting expense during fiscal 2020   $ 19     $ 7     $ 1     $ 1     $ 28  
(1) On March 24, 2020, Emera completed the sale of Emera Maine.

 

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MANAGEMENT’S DISCUSSION & ANALYSIS

 

OFF-BALANCE SHEET ARRANGEMENTS

 

DEFEASANCE 

Upon privatization in 1992, NSPI became responsible for managing a portfolio of defeasance securities that provide principal and interest streams to match the related defeased debt, which at December 31, 2020 totalled $582 million (2019 – $740 million). The securities are held in trust for an affiliate of the Province of Nova Scotia. Approximately 78 per cent of the defeasance portfolio consists of investments in the related debt, eliminating all risk associated with this portion of the portfolio; the remaining defeasance portfolio has a market value higher than the related debt, reducing the future risk of this portion of the portfolio.

 

GUARANTEES AND LETTERS OF CREDIT 

Emera has guarantees and letters of credit on behalf of third parties outstanding. The following significant guarantees and letters of credit are not included within the Consolidated Balance Sheets as at December 31, 2020:

 

TECO Energy has issued a guarantee in connection with SeaCoast’s performance of obligations under a gas transportation precedent agreement. The guarantee is for a maximum potential amount of $45 million USD if SeaCoast fails to pay or perform under the contract. The guarantee expires five years after the gas transportation precedent agreement termination date, which is expected to terminate on January 1, 2022. In the event that TECO Energy’s and Emera’s long-term senior unsecured credit ratings are downgraded below investment grade by Moody’s or S&P, TECO Energy would be required to provide its counterparty a letter of credit or cash deposit of $27 million USD.

 

Emera Inc. has issued a guarantee of up to $35 million USD relating to outstanding notes of GBPC. The guarantee for the notes will expire in May 2023.

 

NSPI has issued guarantees in the amount of $18 million USD on behalf of its subsidiary, NS Power Energy Marketing Incorporated (“NSPEMI”), to secure obligations under purchase agreements with third-party suppliers. The guarantees have terms of varying lengths and will be renewed as required.

 

The Company has standby letters of credit and surety bonds in the amount of $55 million USD (December 31, 2019 – $82 million USD) to third parties that have extended credit to Emera and its subsidiaries. These letters of credit and surety bonds typically have a one-year term and are renewed annually as required.

 

Emera Inc., on behalf of NSPI, has a standby letter of credit to secure obligations under a supplementary retirement plan. The expiry date of this letter of credit was extended to June 2021. The amount committed as at December 31, 2020 was $63 million (December 31, 2019 – $52 million).

 

DIVIDEND PAYOUT RATIO

 

Emera has provided annual dividend growth guidance of four to five per cent through 2022. The Company targets a long-term dividend payout ratio of 70 to 75 per cent, and while the payout ratio is likely to exceed that target through and beyond the forecast period, it is expected to return to that range over time. Emera Incorporated’s common share dividends paid in 2020 were $2.4750 ($0.6125 in Q1, Q2, and Q3 and $0.6375 in Q4) per common share and $2.3750 ($0.5875 in Q1, Q2, and Q3 and $0.6125 in Q4) per common share for 2019, representing a payout ratio of 91 per cent of adjusted net income in 2020 and 91 per cent in 2019.

 

On September 16, 2020, Emera’s Board of Directors approved an increase in the annual common share dividend rate to $2.55 from $2.45. The first quarterly dividend payment at the increased rate was paid on November 16, 2020.

 

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MANAGEMENT’S DISCUSSION & ANALYSIS

 

TRANSACTIONS WITH RELATED PARTIES

 

In the ordinary course of business, Emera provides energy, construction and other services and enters into transactions with its subsidiaries, associates and other related companies on terms similar to those offered to non-related parties. Intercompany balances and intercompany transactions have been eliminated on consolidation, except for the net profit on certain transactions between non-regulated and regulated entities in accordance with accounting standards for rate-regulated entities. All material amounts are under normal interest and credit terms.

 

Significant transactions between Emera and its associated companies are as follows:

 

Transactions between NSPI and NSPML related to the Maritime Link assessment are reported in the Consolidated Statements of Income. NSPI’s expense is reported in Regulated fuel for generation and purchased power, totalling $139 million for the year ended December 31, 2020 (2019 – $107 million). NSPML is accounted for as an equity investment and therefore, the corresponding earnings related to this revenue are reflected in Income from equity investments.

 

For further details, refer to the “Business Overview and Outlook – Canadian Electric Utilities – ENL” and “Contractual Obligations” sections.

 

Natural gas transportation capacity purchases from M&NP are reported in the Consolidated Statements of Income. Purchases from M&NP reported net in Operating revenues, Non-regulated, totalled $18 million for the year ended December 31, 2020 (2019 – $63 million).

 

There were no significant receivables or payables between Emera and its associated companies reported on Emera’s Consolidated Balance Sheets as at December 31, 2020 and at December 31, 2019.

 

ENTERPRISE RISK AND RISK MANAGEMENT

 

Emera has a business-wide risk management process, overseen by its Enterprise Risk Management Committee and monitored by the Board of Directors, to ensure an effective, consistent and coherent approach to risk management. Certain risk management activities for Emera are overseen by the Enterprise Risk Management Committee to ensure such risks are appropriately assessed, monitored and subject to appropriate controls and, in the case of certain credit risks, controlled within predetermined financial risk tolerances established through approved policies.

 

The Company’s financial risk management activities are focused on those areas that most significantly impact profitability, quality and consistency of income, and cash flow. Emera’s risk management focus extends to key operational risks including safety and environment, which represent core values of Emera. In this section, Emera describes the principal risks that management believes could materially affect its business, revenues, operating income, net income, net assets, liquidity or capital resources. The nature of risk is such that no list is comprehensive, and other risks may arise or risks not currently considered material may become material in the future.

 

REGULATORY AND POLITICAL RISK 

The Company’s rate-regulated subsidiaries and certain investments subject to significant influence are subject to risk of the recovery of costs and investments. Regulatory and political risk can include change in regulatory frameworks, shifts in government policy, and regulatory decisions.

 

As cost-of-service utilities with an obligation to serve customers, Emera’s utilities operate under formal regulatory frameworks, and must obtain regulatory approval to change or add rates and/or riders. Costs and investments can be recovered upon approval by the respective regulator as an adjustment to rates and/or riders, which normally requires a public hearing process or may be mandated by other governmental bodies. Emera also holds investments in entities in which it has significant influence, and which are subject to regulatory and political risk including NSPML, LIL, M&NP and Lucelec. As a regulated Group II pipeline, the tolls of Brunswick Pipeline are regulated by the CER on a complaint basis, as opposed to the regulatory approval process described above. In the absence of a complaint, the CER does not normally undertake a detailed examination of Brunswick Pipeline’s tolls, which are subject to a firm service agreement expiring in 2034, with Repsol Energy Canada (“REC”). The agreement provides for a predetermined toll increase in the fifth and fifteenth year of the contract.

 

EMERA 2020 ANNUAL REPORT 53


 

MANAGEMENT’S DISCUSSION & ANALYSIS

 

Changes in government and shifts in government policy can impact the commercial and regulatory frameworks under which Emera and its subsidiaries operate. This includes initiatives regarding deregulation or restructuring of the energy industry. Deregulation or restructuring of the energy industry may result in increased competition and unrecovered costs that could adversely affect operations, net income and cash flows. Recently state and local policies in some US jurisdictions have sought to prevent or limit the ability of utilities to provide customers the choice to use natural gas. Changes in applicable state or local laws and regulations could adversely impact PGS and NMGC.

 

Emera’s rate-regulated subsidiaries are subject to regulatory processes. During public hearing processes, consultants and customer representatives scrutinize the costs, actions and plans of these rate-regulated companies, and their respective regulators determine whether to allow recovery and to adjust rates based upon the evidence and any contrary evidence from other parties. In some circumstances, other government bodies may influence the setting of rates. The subsidiaries manage this regulatory risk through transparent regulatory disclosure, ongoing stakeholder and government consultation and multi-party engagement on aspects such as utility operations, regulatory audits, rate filings and capital plans. The subsidiaries employ a collaborative regulatory approach through technical conferences and, where appropriate, negotiated settlements.

 

GLOBAL CLIMATE CHANGE RISK 

The Company is subject to risks that may arise from the impacts of climate change. There is increasing public concern about climate change and growing support for reducing carbon emissions. Municipal, state, provincial and federal governments have been setting policies and enacting laws and regulations to deal with climate change impacts in a variety of ways, including decarbonization initiatives and promotion of cleaner energy and renewable energy generation of electricity. Refer to “Changes in Environmental Legislation” risk below. Insurance companies have begun to limit their exposure to coal-fired electricity generation and are evaluating the medium and long-term impacts of climate change which may result in fewer insurers, more restrictive coverage and increased premiums. Refer to the “Markets” section below and “Uninsured Risk”.

 

Climate change may lead to increased frequency and intensity of weather events and related impacts such as storms, ice storms, hurricanes, cyclones, heavy rainfall, extreme winds, wildfires, flooding and storm surge. The potential impacts of climate change, such as rising sea levels and larger storm surges from more intense hurricanes, can combine to produce even greater damage to coastal generation and other facilities. Climate change is also characterized by rising global temperatures. Increased air temperatures may bring increased frequency and severity of wildfires within the Company’s service territories. Refer to “Weather Risk” and “System Operating and Maintenance Risks”.

 

The Company has made significant investments to facilitate the use of renewable and lower-carbon energy including wind generation, the Maritime Link in Atlantic Canada, and in Florida, solar generation and the modernization of the Big Bend Power Station. Tampa Electric has taken significant steps to reduce overall emissions at its facilities. Tampa Electric expects to achieve a 45 per cent reduction in GHG emissions compared to 2005 levels by 2023 as a result of its investment in solar and natural gas generation which will reduce coal generation. Since 2005, NSPI has reduced carbon emissions by 35 per cent, exceeding the 2030 reduction target of 30 per cent set at the COP 21 Climate Conference, and expects to achieve a greater-than 50 per cent reduction by 2030; nearly double the Government of Canada’s target set under the Paris Agreement. NSPI expects to achieve compliance with a provincially mandated target of at least 40 per cent of energy generated from renewable sources over the 2020-to-2022 period. Both the Government of Nova Scotia and the Government of Canada have enacted or introduced legislation that includes goals of net-zero GHG emissions by 2050. NSPI continues to work with both the provincial and federal governments on measures to address their carbon reduction goals. Within Emera’s natural gas utilities, there are ongoing efforts to reduce methane and carbon emissions through replacement of aging infrastructure, more efficient operations, operational and supply chain optimization, and support of public policy initiatives that address the effects of climate change.

 

The Company’s long-term capital investment plan includes significant investment across the portfolio in renewable and cleaner generation, infrastructure modernization, storm hardening, energy storage and customer-focused technologies. All these initiatives contribute toward mitigating the potential impacts of climate change. The Company continues to engage with government, regulators, industry partners and stakeholders to share information and participate in the development of climate change related policies and initiatives.

 

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MANAGEMENT’S DISCUSSION & ANALYSIS

 

Physical Impacts 

The Company is subject to physical risks that arise, or may arise, from global climate change, including damage to operating assets from more frequent and intense weather events and from wildfires due to warming air temperatures and increasing drought conditions. Substantially all of the Company’s fossil fueled generation assets are located at or near coastal sites and as such are exposed to the separate and combined effects of rising sea levels and increasing storm intensity, including storm surges and flooding. Refer to “Weather Risk” for further information.

 

These risks are mitigated to an extent through features such as flood walls at certain plants and through the location of plants on higher ground. Planned investments in under-grounding parts of the electricity infrastructure contributes to risk mitigation, as does insurance coverage (for assets other than electricity transmission and distribution assets). In addition, implementation of regulatory mechanisms for recovery of costs, such as storm reserves and regulatory deferral accounts help to smooth out the recovery of storm restoration costs over time.

 

Reputation 

Failure to address issues related to climate change could affect Emera’s reputation with stakeholders, its ability to operate and grow, and the Company’s access to, and cost of, capital. Refer to “Liquidity and Capital Market Risk”. The Company seeks to mitigate this in part by moving away from higher-carbon generation in favour of lower-carbon generation and non-emitting renewable generation.

 

Markets 

Changing carbon-related costs, policy and regulatory changes and shifts in supply and demand factors could lead to more expensive or more scarce products and services that are required by the Company in its operations. This could lead to supply shortages, delivery delays and the need to source alternate products and services. The Company seeks to mitigate these risks through close monitoring of such developments and adaptive changes to supply chain procurement strategies.

 

Given concerns regarding carbon-emitting generation, those assets and businesses may, over time, become difficult (or uneconomic) to insure in commercial insurance markets. In the short term this may be mitigated through increased investment in engineered protection or alternative risk financing (such as funded self-insurance or regulatory structures, including storm reserves). Longer-term mitigation may be achieved through infrastructure siting decisions and further engineered protections. This risk is also mitigated through the continued transition away from high-carbon generation sources to sources with low or zero carbon emissions.

 

Policy 

Government and regulatory initiatives, including greenhouse gas emissions standards, air emissions standards and generation mix standards, are being proposed and adopted in many jurisdictions in response to concerns regarding the effects of climate change. In some jurisdictions, government policy has included timelines for mandated shutdowns of coal generating facilities, carbon pricing, emissions limits and cap and trade mechanisms. Over the medium and longer terms, this could potentially lead to a significant portion of hydrocarbon infrastructure assets being subject to additional regulation and limitations in respect of GHG emissions and operations.

 

The Company is committed to compliance with all climate-related and environmental legislative and regulatory requirements. Such legislative and regulatory initiatives could adversely affect Emera’s operations and financial performance. Refer to “Regulatory and Political Risk” and “Changes in Environmental Legislation” risk. The Company seeks to mitigate these risks through active engagement with governments and regulators to pursue transition strategies that meet the needs of customers, stakeholders and the Company. This has included NSPI’s participation in negotiated equivalency agreements in Nova Scotia to provide for an affordable transition to lower-carbon generation. Equivalency agreements allow NSPI to achieve compliance with federal GHG emissions regulations by meeting provincial legislative and regulatory requirements as they are deemed to be equivalent.

 

Regulatory 

Depending on the regulatory response to government legislation and regulations, the Company may be exposed to the risk of reduced recovery through rates in respect of the affected assets. Valuation impairments could result from such regulatory outcomes. Mitigation efforts in respect of these risks include active engagement with policy makers and regulators to find mechanisms to avoid such impacts while being responsive to customers’ and stakeholders’ objectives.

 

EMERA 2020 ANNUAL REPORT 55


 

MANAGEMENT’S DISCUSSION & ANALYSIS

 

Legal 

The Company could face litigation or regulatory action related to environmental harms from carbon emissions or climate change public disclosure issues. The Company addresses these risks through compliance with all relevant laws, emissions reduction strategies and public disclosure of climate change risks.

 

Water Resources 

For thermal plants requiring cooling water, reduced availability of water resulting from climate change could adversely impact operations or the costs of operations. The Company seeks ways to reduce and recycle water as it does in its Polk power plant in Florida, where recovered and treated wastewater is used in operations to reduce reliance on fresh water supplies in an area where water is not as abundant as in other markets.

 

The Company operates hydroelectric generation in certain of its markets. Such generation depends on availability of water and the hydrological profile of water sources. Changes in precipitation patterns, water temperatures and air temperatures could adversely affect the availability of water and consequently the amount of electricity that may be produced from such facilities. The Company is reinvesting in the efficiency of certain hydroelectric generation facilities to increase generation capacity and continues to monitor changing hydrology patterns. Such issues may also affect the availability of third-party owned hydroelectricity purchased power sources.

 

WEATHER RISK 

The Company is subject to risks that arise or may arise from weather including seasonal variations impacting energy sales, more frequent and intense weather events, changing air temperatures, wildfires and extreme weather conditions associated with climate change. Refer to “Global Climate Change Risk”.

 

Fluctuations in the amount of electricity or natural gas used by customers can vary significantly in response to seasonal changes in weather and could impact the operations, results of operations, financial condition, and cash flows of the Company’s utilities. For example, electrical utilities operating in the US Northeast or Atlantic Canada could see lower demand in winter months if temperatures are warmer than expected. Further, extreme weather conditions such as hurricanes and other severe weather conditions which may be associated with climate change could cause these seasonal fluctuations to be more pronounced. In the absence of a regulatory recovery mechanism for unanticipated costs, such events could influence the Company’s results of operations, financial conditions or cash flows.

 

Extreme weather events create a risk of physical damage to the Company’s assets. High winds can impact structures and cause widespread damage to transmission and distribution infrastructure. Increased frequency and severity of weather events increases the likelihood that the duration of power outages and fuel supply disruptions could increase. Increased intensity of flooding and storm surge could adversely affect the operations of utilities and in particular generation assets.

 

Each of Emera’s regulated electric utilities have programs for storm hardening of transmission and distribution facilities to minimize damage, but there can be no assurance that these measures will fully mitigate the risk. This risk to transmission and distribution facilities is typically not insured, and as such the restoration cost is generally recovered through regulatory processes, either in advance through reserves or designated self-insurance funds, or after the fact through the establishment of regulatory assets. Recovery is not assured and is subject to prudency review. The risk to generation assets is, in part, mitigated through the design, siting, construction and maintenance of such facilities, regular risk assessments, engineered mitigation, emergency storm response plans and insurance.

 

The risk of wildfires is addressed primarily through asset management programs for natural gas transmission and distribution operations, and vegetation management programs for electric transmission and distribution facilities. If it is found to be responsible for such a fire, the Company could suffer costs, losses and damages, all or some of which may not be recoverable through insurance, legal, regulatory cost recovery or other processes. If not recovered through these means, they could materially affect Emera’s business and financial results including its reputation with customers, regulators, governments and financial markets. Resulting costs could include fire suppression costs, regeneration, timber value, increased insurance costs and costs arising from damages and losses incurred by third parties.

 

56 EMERA 2020 ANNUAL REPORT


 

MANAGEMENT’S DISCUSSION & ANALYSIS

 

CHANGES IN ENVIRONMENTAL LEGISLATION 

Emera is subject to regulation by federal, provincial, state, regional and local authorities regarding environmental matters, primarily related to its utility operations. This includes laws setting GHG emissions standards and air emissions standards. Emera is also subject to laws regarding waste management, wastewater discharges and aquatic and terrestrial habitats.

 

In 2019, NSPI completed registration under the Nova Scotia Cap-and-Trade Program Regulations. This provincial carbon pricing program meets the benchmark set by the Government of Canada. In the United States, in June 2019, the Environmental Protection Agency issued the final Affordable Clean Energy (“ACE”) rule. The ACE rule establishes GHG emission guidelines for states to regulate GHG emissions from existing coal-fired electricity generating units. Individual states continue to develop or administer GHG reduction initiatives. Changes to GHG emissions standards and air emissions standards could adversely affect Emera’s operations and financial performance.

 

Legislative or regulatory changes could influence decisions regarding early retirement of generation facilities and may result in stranded costs if the Company is not able to fully recover the costs and investment in the affected generation assets. Recovery is not assured and is subject to prudency review. Legislative or regulatory changes may curtail sales of natural gas to new customers, which could reduce future customer growth in Emera’s natural gas businesses. Stricter environmental laws and enforcement of such laws in the future could increase Emera’s exposure to additional liabilities and costs. These changes could also affect earnings and strategy by changing the nature and timing of capital investments.

 

In addition to imposing continuing compliance obligations, there are permit requirements, laws and regulations authorizing the imposition of penalties for non-compliance, including fines, injunctive relief, and other sanctions. The cost of complying with current and future environmental requirements is, and may be, material to Emera. Failure to comply with environmental requirements or to recover environmental costs in a timely manner through rates could have a material adverse effect on Emera. In addition, Emera’s business could be materially affected by changes in government policy, utility regulation, and environmental and other legislation that could occur in response to environmental and climate change concerns.

 

Emera manages its environmental risk by operating in a manner that is respectful and protective of the environment and in compliance with applicable legal requirements and Company policy. Emera has implemented this policy through the development and application of environmental management systems in its operating subsidiaries. Comprehensive audit programs are in place to regularly test compliance.

 

CYBERSECURITY RISK 

Emera is exposed to potential risks related to cyberattacks and unauthorized access. The Company increasingly relies on information technology systems and network infrastructure to manage its business and safely operate its assets, including controls for interconnected systems of generation, distribution and transmission as well as financial, billing and other business systems. Emera also relies on third-party service providers to conduct business. As the Company operates critical infrastructure, it may be at greater risk of cyberattacks by third parties, which could include nation-state-controlled parties.

 

Cyberattacks can reach the Company’s networks with access to critical assets and information via their interfaces with less critical internal networks or via the public internet. Cyberattacks can also occur via personnel with direct access to critical assets or trusted networks. An outbreak of infectious disease, a pandemic or a similar public health threat, such as COVID-19, may cause disruption in normal working patterns including wide scale “work from home” policies, which could increase cybersecurity risk as the quantity of both cyberattacks and network interfaces increases. Refer to the “Public Health Risk” section below. Methods used to attack critical assets could include general purpose or energy-sector-specific malware delivered via network transfer, removable media, viruses, attachments, or links in e-mails. The methods used by attackers are continuously evolving and can be difficult to predict and detect.

 

Despite security measures in place, that are described below, the Company’s systems, assets and information could experience security breaches that could cause system failures, disrupt operations, or adversely affect safety. Such breaches could compromise customer, employee-related or other information systems and could result in loss of service to customers or the unavailability, release, destruction, or misuse of critical, sensitive or confidential information. These breaches could also delay delivery or result in contamination or degradation of hydrocarbon products the Company transports, stores or distributes.

 

EMERA 2020 ANNUAL REPORT 57


 

MANAGEMENT’S DISCUSSION & ANALYSIS

 

Should such cyberattacks or unauthorized accesses materialize, the Company could suffer costs, losses and damages all, or some of which, may not be recoverable through insurance, legal, regulatory cost recovery or other processes and could materially adversely affect Emera’s business and financial results including its reputation and standing with customers, regulators, governments and financial markets. Resulting costs could include, amongst others, response, recovery and remediation costs, increased protection or insurance costs and costs arising from damages and losses incurred by third parties. If any such security breaches occur, there is no assurance that they can be adequately addressed in a timely manner.

 

The Company seeks to manage these risks by aligning to a common set of cybersecurity standards, periodic security testing, program maturity objectives, strategy derived, in part, on the National Institute of Standards and Technology’s Cyber Security Framework, and employee communication and training. With respect to certain of its assets, the Company is required to comply with rules and standards relating to cybersecurity and information technology including, but not limited to, those mandated by bodies such as the North American Electric Reliability Corporation and Northeast Power Coordinating Council. The status of key elements of the Company’s cybersecurity program is reported to the Audit Committee on a quarterly basis.

 

PUBLIC HEALTH RISK 

An outbreak of infectious disease, a pandemic or a similar public health threat, such as the COVID-19 pandemic, or a fear of any of the foregoing, could adversely impact the Company, including causing operating, supply chain and project development delays and disruptions, labour shortages and shutdowns (including as a result of government regulation and prevention measures), which could have a negative impact on the Company’s operations.

 

Any adverse changes in general economic and market conditions arising as a result of a public health threat could negatively impact demand for electricity and natural gas, revenue, operating costs, timing and extent of capital expenditures, results of financing efforts, or credit risk and counterparty risk; which could result in a material adverse effect on the Company’s business.

 

The extent of the evolving COVID-19 pandemic and its future impact on the Company is uncertain. The Company maintains pandemic and business contingency plans in each of its operations to manage and help mitigate the impact of any such public health threat. The Company’s top priority continues to be the health and safety of its customers and employees.

 

ENERGY CONSUMPTION RISK 

Emera’s rate-regulated utilities are affected by demand for energy based on changing customer patterns due to fluctuations in a number of factors including general economic conditions, customers’ focus on energy efficiency and advancements in new technologies, such as rooftop solar, electric vehicles and battery storage. Government policies promoting distributed generation, and new technology developments that enable those policies, have the potential to impact how electricity enters the system and how it is bought and sold. In addition, increases in distributed generation may impact demand resulting in lower load and revenues. These changes could negatively impact Emera’s operations, rate base, net earnings, and cash flows. The Company’s rate-regulated utilities are focused on understanding customer demand, energy efficiency and government policy to ensure that the impact of these activities benefit customers, that they do not negatively impact the reliability of the energy service and that they are addressed through regulations.

 

FOREIGN EXCHANGE RISK 

The Company is exposed to foreign currency exchange rate changes. Emera operates internationally, with an increasing amount of the Company’s adjusted net income earned outside of Canada. As such, Emera is exposed to movements in exchange rates between the Canadian dollar and, particularly, the US dollar, which could positively or adversely affect results.

 

Consistent with the Company’s risk management policies, Emera manages currency risks through matching US denominated debt to finance its US operations and may use foreign currency derivative instruments to hedge specific transactions and earnings exposure. The Company may enter foreign exchange forward and swap contracts to limit exposure on certain foreign currency transactions such as fuel purchases, revenues streams and capital expenditures, and on net income earned outside of Canada. The regulatory framework for the Company’s rate-regulated subsidiaries permits the recovery of prudently incurred costs, including foreign exchange.

 

The Company does not utilize derivative financial instruments for foreign currency trading or speculative purposes or to hedge the value of its investments in foreign subsidiaries. Exchange gains and losses on net investments in foreign subsidiaries do not impact net income as they are reported in Accumulated Other Comprehensive Income (Loss) (“AOCI”) (“AOCL”).

 

58 EMERA 2020 ANNUAL REPORT


 

MANAGEMENT’S DISCUSSION & ANALYSIS

 

LIQUIDITY AND CAPITAL MARKET RISK 

Liquidity risk relates to Emera’s ability to ensure sufficient funds are available to meet its financial obligations. Emera manages this risk by forecasting cash requirements on a continuous basis to determine whether sufficient funds are available. Liquidity and capital needs could be financed through internally generated cash flows, asset sales, short-term credit facilities, and ongoing access to capital markets. The Company reasonably expects liquidity sources to exceed capital needs.

 

Emera’s access to capital and cost of borrowing is subject to several risk factors, including financial market conditions, market disruptions and ratings assigned by credit rating agencies. Disruptions in capital markets could prevent Emera from issuing new securities or cause the Company to issue securities with less than preferred terms and conditions. Emera’s growth plan requires significant capital investments in property, plant and equipment and the risk associated with changes in interest rates could have an adverse effect on the cost of financing. The inability to access cost-effective capital could have a material impact on Emera’s ability to fund its growth plan. The Company’s future access to capital and cost of borrowing may be impacted by various market disruptions including those related to public health threats, such as the COVID-19 pandemic.

 

Emera is subject to financial risk associated with changes in its credit ratings. There are a number of factors that rating agencies evaluate to determine credit ratings, including the Company’s business and regulatory framework, the ability to recover costs and earn returns, diversification, leverage, liquidity and increased exposure to climate change-related impacts, including increased frequency and severity of hurricanes and other severe weather events. A decrease in a credit rating could result in higher interest rates in future financings, increase borrowing costs under certain existing credit facilities, limit access to the commercial paper market or limit the availability of adequate credit support for subsidiary operations. For certain derivative instruments, if the credit ratings of the Company were reduced below investment grade, the full value of the net liability of these positions could be required to be posted as collateral. Emera manages these risks by actively monitoring and managing key financial metrics with the objective of sustaining investment grade credit ratings.

 

The Company has exposure to its own common share price through the issuance of various forms of stock-based compensation, which affect earnings through revaluation of the outstanding units every period. The Company uses equity derivatives to reduce the earnings volatility derived from stock-based compensation.

 

INTEREST RATE RISK 

Emera utilizes a combination of fixed and floating rate debt financing for operations and capital expenditures, resulting in an exposure to interest rate risk. Emera seeks to manage interest rate risk through a portfolio approach that includes the use of fixed and floating rate debt with staggered maturities. The Company will, from time to time, issue long-term debt or enter interest rate hedging contracts to limit its exposure to fluctuations in floating interest rate debt. Interest rates may be impacted by market disruptions related to public health threats, including the COVID-19 pandemic.

 

For Emera’s regulated subsidiaries, the cost of debt is a component of rates and prudently incurred debt costs are recovered from customers. Regulatory ROE will generally follow the direction of interest rates, such that regulatory ROE’s are likely to fall in times of reducing interest rates and rise in times of increasing interest rates, albeit not directly and generally with a lag period reflecting the regulatory process. Rising interest rates may also negatively affect the economic viability of project development and acquisition initiatives.

 

PROJECT DEVELOPMENT AND LAND USE RIGHTS RISK 

The Company’s capital plan includes significant investment in generation, infrastructure modernization and customer-focused technologies. Any projects planned or currently in construction, particularly significant capital projects, may be subject to risks including, but not limited to, impact on costs from schedule delays, risk of cost overruns, ensuring compliance with operating and environmental requirements and other events within or beyond the Company’s control. The Company’s projects may also require approvals and permits at the federal, provincial, state, regional and local levels. There is no assurance that Emera will be able to obtain the necessary project approvals or applicable permits or receive regulatory approval to recover the costs in rates.

 

Some of the Company’s assets are located on land owned by third parties, including Indigenous Peoples, and may be subject to land claims. Present or future assets may be located on lands that have been used for traditional purposes and therefore subject to specific consultations, consents, or conditions for development or operation. If the Company’s rights to locate and operate its assets on any such lands are subject to expiry or become invalid, it may incur material costs to renew rights or obtain such rights. If reasonable terms for land-use rights cannot be negotiated, the Company may incur significant costs to remove and relocate its assets and restore the land. Additional costs incurred could cause projects to be uneconomical to proceed with.

 

EMERA 2020 ANNUAL REPORT 59


 

MANAGEMENT’S DISCUSSION & ANALYSIS

 

Emera manages these project development and land use rights risks by deploying robust project and risk management approaches, led by teams with extensive experience in large projects. The Company consults with Indigenous Peoples in obtaining approvals, constructing, maintaining and operating such facilities, consistent with laws and public policy frameworks. Emera maintains relationships through on-going communications with stakeholders, including Indigenous Peoples, landowners and governments.

 

COUNTERPARTY RISK 

Emera is exposed to risk related to its reliance on certain key partners, suppliers, and customers, any of which may endure financial challenges resulting from commodity price and market volatility, economic instability or adversity, adverse political or regulatory changes and other causes which may cause or contribute to such parties’ insolvency, bankruptcy, restructuring or default on their contractual obligations to Emera. Emera is also exposed to potential losses related to amounts receivable from customers, energy marketing collateral deposits and derivative assets due to a counterparty’s non-performance under an agreement. Counterparty creditworthiness and the ability of key partners, suppliers and customers to perform their contractual obligations may be affected by economic impacts related to COVID-19.

 

Emera manages this counterparty risk through contractual rights and remedies, regulatory frameworks and by monitoring significant developments with its customers, partners and suppliers. The Company also manages credit risk with policies and procedures for counterparty analysis, exposure measurement, and exposure monitoring and mitigation. Credit assessments may be conducted on new customers and counterparties, and deposits or collateral may be requested on certain accounts. Emera may also seek recovery of unpaid amounts or damages through applicable bankruptcy, insolvency or similar proceedings.

 

COUNTRY RISK 

Earnings outside of Canada constituted 73 per cent of Emera’s earnings in 2020 (2019 – 61 per cent) with the majority from the US. Emera’s investments are currently in regions where political and economic risks are considered by the Company to be acceptable. Emera’s operations in some countries may be subject to changes in economic growth, restrictions on the repatriation of income or capital exchange controls, inflation, the effect of global health, safety and environmental matters, including climate change, or economic conditions and market conditions, and change in financial policy and availability of credit. The Company mitigates this risk through a rigorous approval process for investment, and by forecasting cash requirements on a continuous basis to determine whether sufficient funds are available in all affiliates.

 

COMMODITY PRICE RISK 

The Company’s utility fuel supply is subject to commodity price risk. In addition, Emera Energy is subject to commodity price risk through its portfolio of commodity contracts and arrangements.

 

The Company manages this risk through established processes and practices to identify, monitor, report and mitigate these risks. The Company’s commercial arrangements, including the combination of supply and purchase agreements, asset management agreements, pipeline transportation agreements and financial hedging instruments are all used to manage and mitigate this risk. In addition, its credit policies, counterparty credit assessments, market and credit position reporting, and other risk management and reporting practices, are also used to manage and mitigate this risk.

 

Regulated Utilities 

A large portion of the Company’s utility fuel supply comes from international suppliers and therefore may be exposed to broader global conditions, which may include impacts on delivery reliability and price, despite contracted terms. The Company seeks to manage this risk using financial hedging instruments and physical contracts and through contractual protection with counterparties, where applicable.

 

The majority of Emera’s regulated utilities have adopted and implemented fuel adjustment mechanisms which has further helped manage commodity price risk, as the regulatory framework for the Company’s rate-regulated subsidiaries permits the recovery of prudently incurred fuel costs.

 

Emera Energy Marketing and Trading 

Emera Energy has employed further measures to manage commodity risk. The majority of Emera’s portfolio of electricity and gas marketing and trading contracts and, in particular, its natural gas asset management arrangements, are contracted on a back-to-back basis, avoiding any material long or short commodity positions. However, the portfolio is subject to commodity price risk, particularly with respect to basis point differentials between relevant markets, in the event of an operational issue or counterparty default.

 

60 EMERA 2020 ANNUAL REPORT


 

MANAGEMENT’S DISCUSSION & ANALYSIS

 

To measure commodity price risk exposure, Emera employs a number of controls and processes, including an estimated VaR analysis of its exposures. The VaR amount represents an estimate of the potential change in fair value that could occur from changes in market factors within a given confidence level, if an instrument or portfolio is held for a specified time period. The VaR calculation is used to quantify exposure to market risk associated with physical commodities, primarily natural gas and power positions.

 

FUTURE EMPLOYEE BENEFIT PLAN PERFORMANCE AND FUNDING RISK 

Emera subsidiaries have both defined benefit and defined contribution employee pension plans that cover their employees and retirees. All defined benefit plans are closed to new entrants, except for the TECO Energy Group Retirement Plan. The cost of providing these benefit plans varies depending on plan provisions, interest rates, investment performance and actuarial assumptions concerning the future. The COVID-19 pandemic could have an impact on key actuarial assumptions. Actuarial assumptions include earnings on plan assets, discount rates (interest rates used to determine funding levels, contributions to the plans and the pension and post-retirement liabilities) and expectations around future salary growth, inflation and mortality. Two of the largest drivers of cost are investment performance and interest rates, which are affected by global financial and capital markets. Depending on future interest rates and actual versus expected investment performance, Emera could be required to make larger contributions in the future to fund these plans, which could affect Emera’s cash flows, financial condition and operations.

 

Each of Emera’s employee defined benefit pension plans are managed according to an approved investment policy and governance framework. Emera employs a long-term approach with respect to asset allocation and each investment policy outlines the level of risk which the Company is prepared to accept with respect to the investment of the pension funds in achieving both the Company’s fiduciary and financial objectives. Studies are routinely undertaken every three to five years with the objective that the plans’ asset allocations are appropriate for meeting Emera’s long-term pension objectives.

 

LABOUR RISK 

Emera’s ability to deliver service to its customers and to execute its growth plan depends on attracting, developing and retaining a skilled workforce. Utilities are faced with demographic challenges related to trades, technical staff and engineers with an increasing number of employees expected to retire over the next several years. Failure to attract, develop and retain an appropriately qualified workforce could adversely affect the Company’s operations and financial results. Emera seeks to manage this risk through maintaining competitive compensation programs, a dedicated talent acquisition team, human resources programs and practices including ethics and diversity training, employee engagement surveys, succession planning for key positions and apprenticeship programs.

 

Approximately 35 per cent of Emera’s labour force is represented by unions and subject to collective labour agreements. The inability to maintain or negotiate future agreements on acceptable terms could result in higher labour costs and work disruptions, which could adversely affect service to customers and have an adverse effect on the Company’s earnings, cash flow and financial position. Emera seeks to manage this risk through ongoing discussions and working to maintain positive relationships with local unions. The Company maintains contingency plans in each of its operations to manage and reduce the effect of any potential labour disruption.

 

INFORMATION TECHNOLOGY RISK 

Emera relies on various information technology systems to manage operations. This subjects Emera to inherent costs and risks associated with maintaining, upgrading, replacing and changing these systems. This includes impairment of its information technology, potential disruption of internal control systems, substantial capital expenditures, demands on management time and other risks of delays, difficulties in upgrading existing systems, transitioning to new systems or integrating new systems into its current systems. Emera’s digital transformation strategy, including investment in infrastructure modernization and customer focused technologies, is driving increased investment in information technology solutions, resulting in increased project risks associated with the implementation of these solutions.

 

EMERA 2020 ANNUAL REPORT 61


 

MANAGEMENT’S DISCUSSION & ANALYSIS

 

Emera manages these information technology risks through IT asset lifecycle planning and management, governance, internal auditing and testing of systems, and executive oversight. Employees with extensive subject matter expertise assist in risk identification and mitigation, project management, implementation, change management and training. System resiliency, formal disaster recovery and backup processes, combined with critical incident response practices, ensure that continuity is maintained in the event of any disruptions.

 

INCOME TAX RISK 

The computation of the Company’s provision for income taxes is impacted by changes in tax legislation in Canada, the United States and the Caribbean. Any such changes could affect the Company’s future earnings, cash flows, and financial position. The value of Emera’s existing deferred tax assets and liabilities are determined by existing tax laws and could be negatively impacted by changes in laws. Emera monitors the status of existing tax laws to ensure that changes impacting the Company are appropriately reflected in the Company’s tax compliance filings and financial results.

 

SYSTEM OPERATING AND MAINTENANCE RISKS 

The safe and reliable operation of electric generation and electric and natural gas transmission and distribution systems is critical to Emera’s operations. There are a variety of hazards and operational risks inherent in operating electric utilities and natural gas transmission and distribution pipelines. Electric generation, transmission and distribution operations can be impacted by risks such as mechanical failures, activities of third parties, damage to facilities, solar panels and infrastructure caused by hurricanes, storms, falling trees, lightning strikes, floods, fires and other natural disasters. Natural gas pipeline operations can be impacted by risks such as leaks, explosions, mechanical failures, activities of third parties and damage to the pipelines facilities and equipment caused by hurricanes, storms, floods, fires and other natural disasters. Refer to “Global Climate Change Risk” and “Weather Risk”. Electric utility and natural gas transmission and distribution pipeline operation interruption could negatively affect revenue, earnings, and cash flows as well as customer and public confidence.

 

Emera manages these risks by investing in a highly skilled workforce, operating prudently, preventative maintenance and making effective capital investments. Insurance, warranties, or recovery through regulatory mechanisms may not cover any or all these losses, which could adversely affect the Company’s results of operations and cash flows.

 

UNINSURED RISK 

Emera and its subsidiaries maintain insurance to cover accidental loss suffered to its facilities and to provide indemnity in the event of liability to third parties. This is consistent with Emera’s risk management policies. Certain facilities, in particular coal and other thermal generation, may, over time, become more difficult (or uneconomic) to insure as a result of the impact of global climate change. Refer to “Global Climate Change Risk – Markets”. There are certain elements of Emera’s operations which are not insured. These include a significant portion of its electric utilities’ transmission and distribution assets, as is customary in the industry. The cost of this coverage is not economically viable. In addition, Emera accepts deductibles and self-insured retentions under its various insurance policies. Insurance is subject to coverage limits as well as time sensitive claims discovery and reporting provisions and there can be no assurance that the types of liabilities or losses that may be incurred by the Company and its subsidiaries will be covered by insurance.

 

The occurrence of significant uninsured claims, claims in excess of the insurance coverage limits maintained by Emera and its subsidiaries, or claims that fall within a significant self-insured retention could have a material adverse effect on Emera’s results of operations, cash flows and financial position, if regulatory recovery is not available. A limited portion of Emera’s property and casualty insurance is placed with a wholly owned captive insurance company. If a loss is suffered by the captive insurer, it is not able to recover that loss other than through future premiums.

 

The Company mitigates its uninsured risk by ensuring that insurance limits align with risk exposures, and for uninsured assets and operations, that appropriate risk assessments and mitigation measures are in place. The regulatory framework for the Company’s rate-regulated subsidiaries permits the recovery of prudently incurred costs, including uninsured losses.

 

62 EMERA 2020 ANNUAL REPORT


 

MANAGEMENT’S DISCUSSION & ANALYSIS

 

RISK MANAGEMENT INCLUDING FINANCIAL INSTRUMENTS

 

Emera’s risk management policies and procedures provide a framework through which management monitors various risk exposures. The risk management policies and practices are overseen by the Board of Directors. The Company has established a number of processes and practices to identify, monitor, report on and mitigate material risks to the Company. This includes establishment of the Enterprise Risk Management Committee, whose responsibilities include preparing an updated risk dashboard and heat map quarterly for the Board of Directors. Furthermore, a corporate team independent from operations is responsible for tracking and reporting on market and credit risks.

 

The Company manages exposure to normal operating and market risks relating to commodity prices, foreign exchange, interest rates and share prices through contractual protections with counterparties where practicable, and by using financial instruments consisting mainly of foreign exchange forwards and swaps, interest rate options and swaps, equity derivatives, and coal, oil and gas futures, options, forwards and swaps. In addition, the Company has contracts for the physical purchase and sale of natural gas. Collectively, these contracts and financial instruments are considered derivatives.

 

The Company recognizes the fair value of all its derivatives on its balance sheet, except for non-financial derivatives that meet the normal purchases and normal sales (“NPNS”) exception. A physical contract generally qualifies for the NPNS exception if the transaction is reasonable in relation to the Company’s business needs, the counterparty owns or controls resources within the proximity to allow for physical delivery, the Company intends to receive physical delivery of the commodity, and the Company deems the counterparty creditworthy. The Company continually assesses contracts designated under the NPNS exception and will discontinue the treatment of these contracts under this exemption where the criteria are no longer met.

 

Derivatives qualify for hedge accounting if they meet stringent documentation requirements and can be proven to effectively hedge the identified risk both at the inception and over the term of the instrument. Specifically, for cash flow hedges, the change in the fair value of derivatives is deferred to AOCI and recognized in income in the same period the related hedged item is realized. Where the documentation or effectiveness requirements are not met any changes in fair value are recognized in net income in the reporting period, unless deferred as a result of regulatory accounting.

 

Derivatives entered into by NSPI, NMGC and GBPC that are documented as economic hedges, and for which the NPNS exception has not been taken, are subject to regulatory accounting treatment. These derivatives are recorded at fair value on the balance sheet as derivative assets or liabilities. The change in fair value of the derivatives is deferred to a regulatory asset or liability. The gain or loss is recognized in the hedged item when the hedged item is settled in regulated fuel for generation and purchased power, inventory or property, plant and equipment, depending on the nature of the item being economically hedged. Management believes any gains or losses resulting from settlement of these derivatives will be refunded to or collected from customers in future rates. Tampa Electric and PGS have no derivatives related to hedging as a result of a Florida Public Service Commission approved five-year moratorium on hedging of natural gas purchases which ends on December 31, 2022.

 

Derivatives that do not meet any of the above criteria are designated as HFT and are recognized on the balance sheet at fair value. All gains or losses are recognized in net income of the period unless deferred as a result of regulatory accounting. The Company has not elected to designate any derivatives to be included in the HFT category when another accounting treatment applies.

 

HEDGING ITEMS RECOGNIZED ON THE BALANCE SHEETS 

The Company has the following categories on the balance sheet related to derivatives in valid hedging relationships:

 

As at
millions of Canadian dollars
  December 31
2020
    December 31
2019
 
Derivative instrument assets (current and other assets)   $ 1     $  
Derivative instrument liabilities (current and long-term liabilities)           (1 )
Net derivative instrument assets (liabilities)   $ 1     $ (1 )

 

EMERA 2020 ANNUAL REPORT 63


 

MANAGEMENT’S DISCUSSION & ANALYSIS

 

HEDGING IMPACT RECOGNIZED IN NET INCOME

The Company recognized gains (losses) related to the effective portion of hedging relationships under the following categories:

 

For the
millions of Canadian dollars
        Year ended
December 31
 
    2020     2019  
Operating revenues – regulated   $ (2 )   $ (3 )
Effective net losses   $ (2 )   $ (3 )

 

The effective net losses reflected in the above table are offset in net income by the hedged item realized in the period.

 

REGULATORY ITEMS RECOGNIZED ON THE BALANCE SHEETS 

The Company has the following categories on the balance sheet related to derivatives receiving regulatory deferral:

 

As at
millions of Canadian dollars
  December 31
2020
    December 31
2019
 
Derivative instrument assets (current and other assets)   $ 14     $ 28  
Regulatory assets (current and other assets)     65       80  
Derivative instrument liabilities (current and long-term liabilities)     (62 )     (78 )
Regulatory liabilities (current and long-term liabilities)     (15 )     (42 )
Net asset (liability)   $ 2     $ (12 )

 

REGULATORY IMPACT RECOGNIZED IN NET INCOME 

The Company recognized the following net gains (losses) related to derivatives receiving regulatory deferral as follows:

 

For the
millions of Canadian dollars
        Year ended
December 31
 
    2020     2019  
Regulated fuel for generation and purchased power (1)   $ (21 )   $ 5  
Net gains (losses)   $ (21 )   $ 5  

(1) Realized gains (losses) on derivative instruments settled and consumed in the period, hedging relationships that have been terminated or the hedged transaction is no longer probable. Realized gains (losses) recorded in inventory will be recognized in “Regulated fuel for generation and purchased power” when the hedged item is consumed.

 

HFT ITEMS RECOGNIZED ON THE BALANCE SHEETS 

The Company has the following categories on the balance sheet related to HFT derivatives:

 

As at
millions of Canadian dollars
  December 31
2020
    December 31
2019
 
Derivative instrument assets (current and other assets)   $ 68     $ 58  
Derivative instrument liabilities (current and long-term liabilities)     (275 )     (291 )
Net derivative instrument liability   $ (207 )   $ (233 )

 

HFT ITEMS RECOGNIZED IN NET INCOME 

The Company has recognized the following realized and unrealized gains (losses) with respect to HFT derivatives in net income:

 

For the
millions of Canadian dollars
        Year ended
December 31
 
    2020     2019  
Non-regulated operating revenues   $ 204     $ 282  
Non-regulated fuel for generation and purchased power     (4 )     (6 )
Net gains   $ 200     $ 276  

 

64 EMERA 2020 ANNUAL REPORT


 

MANAGEMENT’S DISCUSSION & ANALYSIS

 

OTHER DERIVATIVES RECOGNIZED ON THE BALANCE SHEETS 

The Company has the following categories on the balance sheet related to other derivatives:

 

As at
millions of Canadian dollars
  December 31
2020
    December 31
2019
 
Derivative instrument assets (current and other assets)   $ 15     $ 1  
Derivative instrument liabilities (current and long-term liabilities)     (1 )      
Net derivative instrument assets   $ 14     $ 1  

 

OTHER DERIVATIVES RECOGNIZED IN NET INCOME 

The Company recognized in net income the following realized and unrealized gains (losses) related to other derivatives:

 

For the
millions of Canadian dollars
      Year ended
December 31
 
    2020   2019  
Operating, maintenance and general   $ (4 ) $ 28  
Other income, net     13      
Net gains   $ 9   $ 28  

 

DISCLOSURE AND INTERNAL CONTROLS

Management is responsible for establishing and maintaining adequate disclosure controls and procedures (“DC&P”) and internal control over financial reporting (“ICFR”), as defined in National Instrument 52-109 Certification of Disclosure in Issuers’ Annual and Interim Filings (“NI 52-109”). The Company’s internal control framework is based on the criteria published in the Internal Control – Integrated Framework (2013), a report issued by the Committee of Sponsoring Organizations (“COSO”) of the Treadway Commission. Management, including the Chief Executive Officer and Chief Financial Officer, evaluated the design and effectiveness of the Company’s DC&P and ICFR as at December 31, 2020 to provide reasonable assurance regarding the reliability of financial reporting in accordance with USGAAP.

 

Management recognizes the inherent limitations in internal control systems, no matter how well designed. Control systems determined to be appropriately designed can only provide reasonable assurance with respect to the reliability of financial reporting and may not prevent or detect all misstatements.

 

There were no changes in the Company’s ICFR, during the year ended December 31, 2020, that have materially affected, or are reasonably likely to materially affect, the Company’s internal control over financial reporting.

 

EMERA 2020 ANNUAL REPORT 65


 

MANAGEMENT’S DISCUSSION & ANALYSIS

 

CRITICAL ACCOUNTING ESTIMATES

Preparation of consolidated financial statements in accordance with USGAAP requires management to make estimates and assumptions. These may affect reported amounts of assets and liabilities at the date of the financial statements and reported amounts of revenues and expenses during the reporting periods. Significant areas requiring use of management estimates relate to rate-regulated assets and liabilities, allowance for credit losses, accumulated reserve for cost of removal, pension and post- retirement benefits, unbilled revenue, useful lives for depreciable assets, goodwill and long-lived assets impairment assessments, income taxes, asset retirement obligations, and valuation of financial instruments. Management evaluates the Company’s estimates on an ongoing basis based upon historical experience, current and expected conditions and assumptions believed to be reasonable at the time the assumption is made, with any adjustments recognized through income in the year they arise.

 

During the year ended December 31, 2020, the ongoing COVID-19 pandemic has affected all service territories in which Emera operates. The pandemic has generally resulted in lower load and higher operating costs than what otherwise would have been experienced at the Company’s utilities. Some of Emera’s utilities have been impacted more than others. However, on a consolidated basis these unfavourable impacts have not had a material financial impact on 2020 net earnings. This was primarily due to a favourable change to the mix of sales across customer classes resulting in the lower commercial and industrial sales being partially offset by increased sales to residential customers, which have a higher contribution to fixed cost recovery. Favourable weather in 2020, in particular in Florida, has further reduced the consolidated impact. Emera’s utilities provide essential services and continue to operate and meet customer demand. Governments world-wide have implemented measures intended to address the pandemic. These measures include travel and transportation restrictions, quarantines, physical distancing, closures of commercial spaces and industrial facilities, shutdowns, shelter-in-place orders and other health measures. These measures are adversely impacting global, national and local economies. In addition, Global equity markets have experienced significant volatility. Governments and central banks are implementing measures designed to stabilize economic conditions. The pace and strength of economic recovery is uncertain and may vary among jurisdictions.

 

Management has analyzed the impact of the COVID-19 pandemic on its estimates and judgments and concluded that no material adjustments were required at December 31, 2020. The extent of the future impact of COVID-19 on the Company’s financial results and business operations cannot be predicted and will depend on future developments, including duration and severity of the pandemic, timing and effectiveness of vaccinations, further potential government actions and future economic activity and energy usage. Actual results may differ significantly from these estimates.

 

RATE REGULATION
The rate-regulated accounting policies of Emera’s rate-regulated subsidiaries and regulated equity investments are subject to examination and approval by their respective regulators and may differ from accounting policies for non-rate-regulated companies. These accounting policy differences occur when the regulators render their decisions on rate applications or other matters, and generally involve a difference in the timing of revenue and expense recognition. The accounting for these items is based on expectations of the future actions of the regulators. Assumptions and judgments used by regulatory authorities continue to have an impact on the recovery of costs, the rate earned on invested capital and the timing and amount of assets to be recovered. The application of regulatory accounting guidance is a critical accounting policy as a change in these assumptions may result in a material impact on reported assets, liabilities and the results of operations.

 

The Company has recorded $1,584 million (2019 – $1,552 million) of regulatory assets and $1,961 million (2019 – $2,181 million) of regulatory liabilities as at December 31, 2020.

 

ACCUMULATED RESERVE - COST OF REMOVAL 

Tampa Electric, PGS, NMGC and NSPI recognize non-asset retirement obligation costs of removal as regulatory liabilities. These costs of removal represent estimated funds received from customers through depreciation rates to cover future non-legally required costs of removal of property, plant and equipment upon retirement. The companies accrue for costs of removal over the life of the related assets based on depreciation studies approved by their respective regulators. Costs are estimated based on historical experience and future expectations, including expected timing and estimated future cash outlays. The balance of the Accumulated reserve – cost of removal within regulatory liabilities was $866 million at December 31, 2020 (2019 – $891 million).

 

66 EMERA 2020 ANNUAL REPORT


 

MANAGEMENT’S DISCUSSION & ANALYSIS

 

PENSION AND OTHER POST- RETIREMENT EMPLOYEE BENEFITS

The Company provides post-retirement benefits to employees, including defined benefit pension plans. The cost of providing these benefits is dependent upon many factors that result from actual plan experience and assumptions of future expectations.

 

The accounting related to employee post-retirement benefits is a critical accounting estimate. Changes in the estimated benefit obligation, affected by employee demographics, including age, compensation levels, employment periods, contribution levels and earnings, could have a material impact on reported assets, liabilities, accumulated other comprehensive income and results of operations. The COVID-19 pandemic could have an impact on key actuarial assumptions. Changes in key actuarial assumptions, including anticipated rates of return on plan assets and discount rates used in determining the accrued benefit obligation and benefit costs could change annual funding requirements. This could have a significant impact on the Company’s annual earnings and cash requirements.

 

The pension plan assets are comprised primarily of equity and fixed income investments. Fluctuations in actual equity market returns and changes in interest rates may result in changes to pension costs in future periods.

 

The Company’s accounting policy is to amortize the net actuarial gain or loss, that exceeds 10 per cent of the greater of the projected benefit obligation / accumulated post-retirement benefit obligation (“PBO”) and the market-related value of assets, over active plan members’ average remaining service period. For the largest plans this is currently 9.4 years (9.8 years for 2020 benefit cost) for the Canadian plans and a weighted average of 12.1 years for the US plans). The Company’s use of smoothed asset values reduces volatility related to the amortization of actuarial investment experience. As a result, the main cause of volatility in reported pension cost is the discount rate used to determine the PBO.

 

The discount rate used to determine benefit costs is based on the yield of high quality long-term corporate bonds in each operating entity’s country and is determined with reference to bonds which have the same duration as the PBO as at January 1 of the fiscal year. The following table shows the discount rate for benefit cost purposes and the expected return on plan assets for each plan:

 

        2020       2019  
    Discount rate
for benefit
cost purposes
  Expected
return on
plan assets
  Discount rate
for benefit
cost purposes
  Expected
return on
plan assets
 
TECO Energy Group Retirement Plan   3.22%   7.00%   4.34% / 3.13%   7.35% / 7.00%  
TECO Energy Group Supplemental Executive Retirement Plan (1)   2.78%   N/A   4.02%   N/A  
TECO Energy Group Benefit Restoration Plan (1)   2.81%   N/A   4.12% / 3.94% / 3.32%   N/A  
TECO Energy Post-retirement Health and Welfare Plan   3.32%   N/A   4.38%   N/A  
New Mexico Gas Company Retiree Medical Plan   3.32%   3.25%   4.39%   3.25%  
NSPI   3.13%, 3.21%   5.75%   3.83%   6.00%  
GBPC Salaried   4.25%   6.00%   4.25%   6.00%  
GBPC Union   5.00%   5.00%   5.00%   5.00%  

(1) The discount rate and expected return on assets for benefit cost purposes is updated throughout the year as special events occur, such as settlements and curtailments.

(2) On March 24, 2020, Emera completed the sale of Emera Maine. The discount rate for benefit cost purposes and expected return on plan assets up until the time of sale was 3.18% (2019 – 4.19%) and 6.35% (2019 – 6.35%) for Bangor Hydro and 3.09% (2019 – 4.12%) and 6.55% (2019 – 6.55%) for Maine Public Service.

 

Based on management’s estimate, the reported benefit cost for defined benefit and defined contribution plans was $87 million in 2020 (2019 – $84 million). The reported benefit cost is impacted by numerous assumptions, including the discount rate and asset return assumptions. A 0.25 per cent change in the discount rate and asset return assumptions would have had +/- impact on the 2020 benefit cost of $6 million and $5 million respectively (2019 – $9 million and $6 million).

 

EMERA 2020 ANNUAL REPORT 67


 

MANAGEMENT’S DISCUSSION & ANALYSIS

 

UNBILLED REVENUE
Electric and gas revenues are billed on a systematic basis over a one or two-month period for NSPI and a one-month period for other Emera utilities. At the end of each month, the Company must make an estimate of energy delivered to customers since the date their meter was last read and determine related revenues earned but not yet billed. The unbilled revenue is estimated based on several factors, including current month’s generation, estimated customer usage by class, weather, line losses, inter-period changes to customer classes and applicable customer rates. Based on the extent of the estimates included in the determination of unbilled revenue, actual results may differ from the estimate. At December 31, 2020, unbilled revenues totalled $286 million (2019 – $265 million) on total regulated operating revenues of $5,476 million (2019 – $5,850 million).

 

PROPERTY, PLANT AND EQUIPMENT
Property, plant and equipment represents 63 per cent of total assets on the Company’s balance sheet. Included in “Property, plant and equipment” are the generation, transmission and distribution and other assets of the Company.

 

Depreciation is determined by the straight-line method, based on the estimated remaining service lives of the depreciable assets in each category. The service lives of regulated property, plant and equipment are determined based on depreciation studies and require appropriate regulatory approval. Due to the magnitude of the Company’s property, plant and equipment, changes in estimated depreciation rates can have a material impact on depreciation expense and accumulated depreciation.

 

Depreciation expense was $860 million for the year ended December 31, 2020 (2019 – $881 million).

 

GOODWILL IMPAIRMENT ASSESSMENTS
Goodwill is subject to an annual assessment for impairment at the reporting unit level with interim impairment tests performed when impairment indicators are present. Reporting units are generally determined at the operating segment level or one level below the operating segment level. Reporting units with similar characteristics are grouped for the purpose of determining impairment, if any, of goodwill. Application of the goodwill impairment test requires management judgment on significant assumptions and estimates. Entities assessing goodwill for impairment have the option of first performing a qualitative assessment to determine whether a quantitative assessment is necessary. Significant assumptions used in the qualitative assessment include macroeconomic conditions, industry and market considerations and overall financial performance, among other factors.

 

If the Company performs the qualitative assessment but determines that it is more likely than not that its fair value is less than its carrying amount, or if the Company chooses to bypass the qualitative assessment, a quantitative test is performed. The quantitative test compares the fair value of the reporting unit to its carrying amount, including goodwill. If the carrying amount of the reporting unit exceeds its fair value, an impairment loss is recorded as a reduction to goodwill and a charge to operating expense. Significant assumptions used in estimating the fair value include discount and growth rates, rate case assumptions, valuation of the reporting units’ net operating loss (“NOL”), utility sector market performance and transactions, projected operating and capital cash flows and the fair value of debt. As part of the 2020 goodwill impairment assessment management considered potential impacts of the COVID-19 pandemic on future earnings of the reporting units.

 

As of December 31, 2020, the Company had goodwill with a total carrying amount of $5,720 million (December 31, 2019 – $5,835 million). This goodwill represents the excess of the acquisition purchase price for TECO Energy (Tampa Electric, PGS and NMGC reporting units) and GBPC over the fair values assigned to identifiable assets acquired and liabilities assumed. The change in the carrying value of goodwill from 2019 to 2020 was a result of the strengthening Canadian dollar on the goodwill balances.

 

As of December 31, 2020, $5,649 million of Emera’s goodwill was related to TECO Energy (Tampa Electric, PGS and NMGC reporting units). A qualitative assessment was performed for these reporting units given the significant excess of fair value over carrying amounts calculated during the last quantitative test in Q4 2019. Management concluded that it was more likely than not that the fair value of these reporting units exceeded their respective carrying amounts, including goodwill. As such, no quantitative testing was required.

 

A GBPC goodwill impairment charge of $30 million was recorded in 2019 due to a decrease in expected future cash flows resulting from the impacts of Hurricane Dorian storm recovery and changes in the anticipated long term regulated capital structure of GBPC. As of December 31, 2020, $68 million of Emera’s goodwill was related to GBPC. In Q4 2020, the Company performed a quantitative impairment assessment for GBPC as this reporting unit is more sensitive to changes in forecasted future earnings due to limited excess of fair value over the carrying value. The assessment estimated that the fair value of the reporting unit exceeded its carrying value, including goodwill, by approximately five per cent. Adverse changes in significant assumptions could result in a future impairment. For further detail, refer to note 22 to the consolidated financial statements.

 

68 EMERA 2020 ANNUAL REPORT


 

MANAGEMENT’S DISCUSSION & ANALYSIS

 

The fair market value of reporting units is subject to change from period to period as assumptions about future cash flows are required. Adverse regulatory actions, such as significant reductions in the allowed ROE at Tampa Electric, PGS, NMGC or GBPC could negatively impact goodwill in the future. In addition, changes in other fair value significant assumptions described above could also negatively impact goodwill in the future.

 

LONG-LIVED ASSETS IMPAIRMENT ASSESSMENTS
In accordance with accounting guidance for long-lived assets, the Company assesses whether there has been an impairment of long-lived assets and intangibles when a triggering event occurs, such as a significant market disruption or the sale of a business. Review of long-lived assets for impairment involves comparing the undiscounted expected future cash flows to the carrying value of the asset. When the undiscounted cash flow analysis indicates a long-lived asset is not recoverable, the amount of the impairment loss is determined by measuring the excess of the carrying amount of the long-lived asset over its estimated fair value.

 

The Company believes accounting estimates related to asset impairments are critical estimates as they are highly susceptible to change and the impact of an impairment on reported assets and earnings could be material. Management is required to make assumptions based on expectations regarding the results of operations for significant/indefinite future periods and the current and expected market conditions in such periods. Markets can experience significant uncertainties. Estimates based on the Company’s assumptions relating to future results of operations or other recoverable amounts are based on a combination of historical experience, fundamental economic analysis, observable market activity and independent market studies. The Company’s expectations regarding uses and holding periods of assets are based on internal long-term budgets and projections, which consider external factors and market forces, as of the end of each reporting period. Assumptions made are consistent with generally accepted industry approaches and assumptions used for valuation and pricing activities.

 

Management considered whether the potential impacts of the COVID-19 pandemic on undiscounted future cash flows could indicate that long-lived assets are not recoverable. As at December 31, 2020, there were no indications of impairment of Emera’s long-lived assets. The impact of COVID-19 could cause the Company to impair long-lived assets in the future; however, there is currently no indication that future cash flows would be impacted to a point where the Company’s long-lived assets would not be recoverable.

 

In Q1 2020, impairment charges of $25 million ($26 million after tax) were recognized on certain assets and recorded in Impairment Charge on the Consolidated Income Statement. In 2019, as a result of Hurricane Dorian, Grand Bahama recognized an impairment of $18 million USD which has been fully recovered through insurance.

 

INCOME TAXES
Income taxes are determined based on the expected tax treatment of transactions recorded in the consolidated financial statements. In determining income taxes, tax legislation is interpreted in a variety of jurisdictions, the likelihood that deferred tax assets will be recovered from future taxable income is assessed and assumptions about the expected timing of the reversal of deferred tax assets and liabilities are made. Uncertainty associated with application of tax statutes and regulations and the outcomes of tax audits and appeals, requires that judgments and estimates be made in the accrual process and in the calculation of effective tax rates. Only income tax benefits that meet the “more likely than not” threshold may be recognized or continue to be recognized. Unrecognized tax benefits are evaluated quarterly and changes are recorded based on new information, including issuance of relevant guidance by the courts or tax authorities and developments occurring in examinations of the Company’s tax returns.

 

The Company believes the accounting estimate related to income taxes is a critical estimate. The realization of deferred tax assets is dependent upon the generation of sufficient taxable income, both operating and capital, in future periods. A change in the estimated valuation allowance could have a material impact on reported assets and results of operations. Administrative actions of the tax authorities, changes in tax law or regulation, and the uncertainty associated with the application of tax statutes and regulations could change the Company’s estimate of income taxes, including the potential for elimination or reduction of our ability to realize tax benefits and to utilize deferred tax assets.

 

EMERA 2020 ANNUAL REPORT 69


 

MANAGEMENT’S DISCUSSION & ANALYSIS

 

ASSET RETIREMENT OBLIGATIONS (“ARO”)
Measurement of the fair value of AROs requires the Company to make reasonable estimates concerning the method and timing of settlement associated with the legally obligated costs. There are uncertainties in estimating future asset-retirement costs due to potential events, such as changing legislation or regulations and advances in remediation technologies. Emera has AROs associated with the remediation of generation, transmission, distribution and pipeline assets.

 

An ARO represents the fair value of the estimated cash flows necessary to discharge the future obligation using the Company’s credit-adjusted risk-free rate. The amounts are reduced by actual expenditures incurred. Estimated future cash flows are based on completed depreciation studies, remediation reports, prior experience, estimated useful lives and governmental regulatory requirements. The present value of the liability is recorded and the carrying amount of the related long-lived asset is correspondingly increased. The amount capitalized at inception is depreciated in the same manner as the related long-lived asset. Over time, the liability is accreted to its estimated future value. Accretion expense is included as part of “Depreciation and amortization expense”. Any accretion expense not yet approved by the regulator is recorded in “Property, plant and equipment” and included in the next depreciation study. Accordingly, changes to the ARO or cost recognition attributable to changes in the factors discussed above, should not impact the results of operations of the Company.

 

Some generation, transmission and distribution assets may have conditional AROs, which are required to be estimated and recorded as a liability. A conditional ARO refers to a legal obligation to perform an asset retirement activity in which the timing and/or method of settlement are conditional on a future event that may or may not be within the control of the entity. Management monitors these obligations and a liability is recognized at fair value when an amount can be determined.

 

As at December 31, 2020, AROs recorded on the balance sheet were $178 million (2019 – $185 million). The Company estimates the undiscounted amount of cash flow required to settle the obligations is approximately $432 million (2019 – $422 million), which will be incurred between 2021 and 2061. The majority of these costs will be incurred between 2028 and 2050.

 

FINANCIAL INSTRUMENTS
The Company is required to determine the fair value of all derivatives except those which qualify for the normal purchase, normal sale exception. Fair value is the price that would be received for the sale of an asset or paid to transfer a liability in an orderly arms-length transaction between market participants at the measurement date. Fair value measurements are required to reflect the assumptions that market participants would use in pricing an asset or liability based on the best available information, including the risks inherent in a particular valuation technique, such as a pricing model, and the risks inherent in the inputs to the model.

 

LEVEL DETERMINATIONS AND CLASSIFICATIONS
The Company uses Level 1, 2, and 3 classifications in the fair value hierarchy. The fair value measurement of a financial instrument is included in only one of the three levels and is based on the lowest level input significant to the derivation of the fair value. Fair values are determined, directly or indirectly, using inputs that are observable for the asset or liability. Only in limited circumstances does the Company enter into commodity transactions involving non-standard features where market observable data is not available or have contract terms that extend beyond five years.

 

CHANGES IN ACCOUNTING POLICIES AND PRACTICES

 

The new USGAAP accounting policies that are applicable to, and adopted by the Company in 2020, are described as follows:

 

MEASUREMENT OF CREDIT LOSSES ON FINANCIAL INSTRUMENTS
The Company adopted Accounting Standard Update (“ASU”) 2016-13, Measurement of Credit Losses on Financial Instruments effective January 1, 2020. The standard provides guidance regarding the measurement of credit losses for financial assets and certain other instruments that are not accounted for at fair value through net income. These include trade and other receivables, debt securities, net investment in leases, and off-balance sheet credit exposures. The new guidance requires companies to replace the current incurred loss impairment methodology with a methodology that measures all expected credit losses for financial assets based on historical experience, current conditions, and reasonable and supportable forecasts. The guidance expands the disclosure requirements regarding credit losses, including the credit loss methodology and credit quality indicators. The adoption of the standard resulted in a $7 million decrease to retained earnings in the consolidated financial statements as of January 1, 2020.

 

70 EMERA 2020 ANNUAL REPORT


 

MANAGEMENT’S DISCUSSION & ANALYSIS

 

SIMPLIFYING THE ACCOUNTING FOR INCOME TAXES
In December 2019, the FASB issued ASU 2019-12, Simplifying the Accounting for Income Taxes. The standard simplifies the accounting for income taxes by eliminating certain exceptions to the guidance in ASC 740 related to the approach for intraperiod tax allocation. It also simplifies aspects of accounting for franchise taxes and enacted changes in tax laws or rates and clarifies the accounting for transactions that result in a step-up in the tax basis of goodwill. The guidance is effective for annual reporting periods, including interim reporting within those periods, beginning after December 15, 2020, with early adoption permitted. The standard is applied on both a prospective and retrospective basis. The Company early adopted the standard effective January 1, 2020. There was no impact on the consolidated financial statements as a result of the adoption of this standard.

 

FACILITATION OF THE EFFECTS OF REFERENCE RATE REFORM ON FINANCIAL REPORTING
The Company adopted ASU 2020-04, Reference Rate Reform (Topic 848): Facilitation of the Effects of Reference Rate Reform on Financial Reporting in Q4 2020. The standard provides options and exceptions for applying USGAAP to contract modifications and hedging relationships that reference the London Inter-Bank Offered Rate (“LIBOR”) or any other reference rate that is expected to be discontinued. The guidance was effective as of the date of issuance and entities may elect to apply the guidance prospectively through December 31, 2022. The Company’s transition from reference rates will not have a material impact on the consolidated financial statements. In November 2020, the Federal Reserve extended the phase-out of LIBOR until June 2023. The Company will continue to monitor the impact this may have on application of the standard.

 

FUTURE ACCOUNTING PRONOUNCEMENTS

 

The Company considers the applicability and impact of all ASUs issued by the FASB. The following updates have been issued by the FASB, but as allowed, have not yet been adopted by Emera. Any ASUs not included below were assessed and determined to be either not applicable to the Company or have an insignificant impact on the consolidated financial statements.

 

ACCOUNTING FOR CONVERTIBLE INSTRUMENTS AND CONTRACTS IN AN ENTITY’S OWN EQUITY
In August 2020, the FASB issued ASU 2020-06, Debt – Debt with Conversion and Other Options (Subtopic 470-20) and Derivatives and Hedging – Contracts in Entity’s Own Equity (Subtopic 815-40). The standard simplifies the accounting for convertible debenture debt instruments and convertible preferred stock, in addition to amending disclosure requirements. The standard also updates guidance for the derivative scope exception for contracts in an entity’s own equity and the related earnings per share guidance. The guidance will be effective for annual reporting periods, including interim reporting within those periods, beginning after December 15, 2021. Early adoption is permitted, but no earlier than fiscal years beginning after December 15, 2020. The standard can be applied through either a modified retrospective method of transition or a fully retrospective method of transition. The Company early adopted the standard effective January 1, 2021 using the modified retrospective method. There was no material impact on the consolidated financial statements as a result of the adoption of this standard.

 

GUARANTEED DEBT SECURITIES DISCLOSURE REQUIREMENTS
In October 2020, the FASB issued ASU 2020-09, Debt (Topic 470): Amendments to SEC Paragraphs pursuant to SEC Release No. 33-10762. The change in the standard aligns with new SEC rules relating to changes to the disclosure requirements for certain registered debt securities that are guaranteed. The changes include simplifying disclosure, enhancing certain narrative disclosures and permitting the disclosures to be made outside of the financial statements. The guidance will be effective for annual reports filed for fiscal years ending after January 4, 2021, with early adoption permitted. The Company is currently evaluating the impact of adoption of the standard on its consolidated financial statements.

 

EMERA 2020 ANNUAL REPORT 71


 

MANAGEMENT’S DISCUSSION & ANALYSIS

 

SUMMARY OF QUARTERLY RESULTS

 

For the quarter ended
millions of Canadian dollars
(except per share amounts)
  Q4
2020
    Q3
2020
    Q2
2020
    Q1
2020
    Q4
2019
    Q3
2019
    Q2
2019
    Q1
2019
 
Operating revenues   $ 1,537     $ 1,163     $ 1,169     $ 1,637     $ 1,616     $ 1,299     $ 1,378     $ 1,818  
Net income attributable to common shareholders     273       84       58       523       193       55       103       312  
Adjusted net income attributable to common shareholders     188       166       118       193       145       122       130       224  
Earnings per common share – basic     1.09       0.34       0.24       2.14       0.79       0.23       0.43       1.32  
Earnings per common share – diluted     1.08       0.34       0.23       2.13       0.80       0.23       0.43       1.32  
Adjusted earnings per common share – basic     0.75       0.67       0.48       0.79       0.60       0.51       0.54       0.95  

 

Quarterly operating revenues and adjusted net income attributable to common shareholders are affected by seasonality. The first quarter provides strong earnings contributions due to a significant portion of the Company’s operations being in northeastern North America, where winter is the peak electricity usage season. The third quarter provides strong earnings contributions due to summer being the heaviest electric consumption season in Florida. Seasonal and other weather patterns, as well as the number and severity of storms, can affect demand for energy and the cost of service. Quarterly results could also be affected by items outlined in the “Significant Items Affecting Earnings” section. In 2020, quarterly results include the impact of the COVID-19 pandemic commencing in March 2020. For further detail, refer to the “Business Overview and Outlook” section.

  

72 EMERA 2020 ANNUAL REPORT


 

MANAGEMENT REPORT

 

MANAGEMENT REPORT

 

Management’s Responsibility for Financial Reporting

 

The accompanying consolidated financial statements of Emera Incorporated and the information in this annual report are the responsibility of management and have been approved by the Board of Directors (“Board”).

 

The consolidated financial statements have been prepared by management in accordance with United States Generally Accepted Accounting Principles. When alternative accounting methods exist, management has chosen those it considers most appropriate in the circumstances. In preparation of these consolidated financial statements, estimates are sometimes necessary when transactions affecting the current accounting period cannot be finalized with certainty until future periods. Management represents that such estimates, which have been properly reflected in the accompanying consolidated financial statements, are based on careful judgments and are within reasonable limits of materiality. Management has determined such amounts on a reasonable basis in order to ensure that the consolidated financial statements are presented fairly in all material respects. Management has prepared the financial information presented elsewhere in the annual report and has ensured that it is consistent with that in the consolidated financial statements.

 

Emera Incorporated maintains effective systems of internal accounting and administrative controls, consistent with reasonable cost. Such systems are designed to provide reasonable assurance that the financial information is reliable and accurate, and that Emera Incorporated’s assets are appropriately accounted for and adequately safeguarded.

 

The Board is responsible for ensuring that management fulfils its responsibilities for financial reporting and is ultimately responsible for reviewing and approving the consolidated financial statements. The Board carries out this responsibility principally through its Audit Committee.

 

The Audit Committee is appointed by the Board, and its members are directors who are not officers or employees of Emera Incorporated. The Audit Committee meets periodically with management, as well as with the internal auditors and with the external auditors, to discuss internal controls over the financial reporting process, auditing matters and financial reporting issues, to satisfy itself that each party is properly discharging its responsibilities, and to review the annual report, the consolidated financial statements and the external auditors’ report. The Audit Committee reports its findings to the Board for consideration when approving the consolidated financial statements for issuance to the shareholders. The Audit Committee also considers, for review by the Board and approval by the shareholders, the appointment of the external auditors.

 

The consolidated financial statements have been audited by Ernst & Young LLP, the external auditors, in accordance with Canadian Generally Accepted Auditing Standards and with the standards of the Public Company Accounting Oversight Board. Ernst & Young LLP has full and free access to the Audit Committee.

 

February 16, 2021

 

(GRAPHIC) (GRAPHIC)
   
“Scott Balfour”
President and Chief Executive Officer
“Gregory Blunden”
Chief Financial Officer
   

 

EMERA 2020 ANNUAL REPORT 73


 

INDEPENDENT AUDITOR’S REPORT

 

INDEPENDENT AUDITOR’S REPORT

 

To the Shareholders and the Board of Directors of Emera Incorporated

 

Opinion 

We have audited the consolidated financial statements of Emera Incorporated (the “Company”), which comprise the Consolidated Balance Sheets as at December 31, 2020 and 2019, and the Consolidated Statements of Income, Consolidated Statements of Comprehensive Income, Consolidated Statements of Changes in Equity and Consolidated Statements of Cash Flows for the years then ended, and notes to the consolidated financial statements, including a summary of significant accounting policies.

 

In our opinion, the accompanying consolidated financial statements present fairly, in all material respects, the consolidated financial position of the Company as at December 31, 2020 and 2019, and the consolidated results of its operations and its consolidated cash flows for the years then ended in accordance with United States generally accepted accounting principles (“USGAAP”).

 

Basis for opinion 

We conducted our audit in accordance with Canadian generally accepted auditing standards. Our responsibilities under those standards are further described in the Auditor’s responsibilities for the audit of the consolidated financial statements section of our report. We are independent of the Company in accordance with the ethical requirements that are relevant to our audit of the consolidated financial statements in Canada, and we have fulfilled our other ethical responsibilities in accordance with these requirements. We believe that the audit evidence we have obtained is sufficient and appropriate to provide a basis for our opinion.

 

Key audit matters 

Key audit matters are those matters that, in our professional judgment, were of most significance in the audit of the consolidated financial statements of the current period. These matters were addressed in the context of the audit of the consolidated financial statements as a whole, and in forming the auditor’s opinion thereon, and we do not provide a separate opinion on these matters. For each matter below, our description of how our audit addressed the matter is provided in that context.

 

We have fulfilled the responsibilities described in the Auditor’s responsibilities for the audit of the consolidated financial statements section of our report, including in relation to these matters. Accordingly, our audit included the performance of procedures designed to respond to our assessment of the risks of material misstatement of the consolidated financial statements. The results of our audit procedures, including the procedures performed to address the matters below, provide the basis for our audit opinion on the accompanying consolidated financial statements.

 

    Accounting for the effects of rate regulation
Key Audit Matter  

As disclosed in note 7 of the consolidated financial statements, the Company has $1.6 billion in regulatory assets and $2.0 billion in regulatory liabilities. The Company’s rate-regulated subsidiaries are subject to regulation by various federal, state and provincial regulatory authorities in the geographic regions in which they operate. The regulatory rates are designed to recover the prudently incurred costs of providing the regulated products or services and provide a reasonable return on the equity invested or assets, as applicable. In addition to regulatory assets and liabilities, rate regulation impacts multiple financial statement line items, including property, plant and equipment, operating revenues and expenses, income taxes, and depreciation expense.

 

Auditing the impact of rate regulation on the Company’s financial statements is complex and highly judgmental due to the significant judgments made by the Company to support its accounting and disclosure for regulatory matters when final regulatory decisions or orders have not yet been obtained or when regulatory formulas are complex. There is also subjectivity involved in assessing the potential impact of future regulatory decisions on the financial statements. Although the Company expects to recover costs from customers through rates, there is a risk that the regulator will not approve full recovery of the costs incurred. The Company’s judgments include making an assessment of the probability of recovery of and recovery on costs incurred, of the disallowance of part of the cost of recently completed property, plant and equipment and construction work in progress, or of the probable refund to customers through future rates. 

 

74 EMERA 2020 ANNUAL REPORT


 

INDEPENDENT AUDITOR’S REPORT

 

    Accounting for the effects of rate regulation
How Our Audit Addressed the Key Audit Matter  

We performed audit procedures that included, amongst others, assessing the Company’s evaluation of the probability of future recovery for regulatory assets, property, plant and equipment, and refund of regulatory liabilities by obtaining and reviewing relevant regulatory orders, filings, testimony, hearings and correspondence, and other publicly available information. For regulatory matters for which regulatory decisions or orders have not yet been obtained, we inspected the rate-regulated subsidiaries’ filings for any evidence that might contradict the Company’s assertions, and reviewed other regulatory orders, filings and correspondence for other entities within the same or similar jurisdictions to assess the likelihood of recovery in future rates based on the regulator’s treatment of similar costs under similar circumstances. We obtained and evaluated an analysis from the Company and corroborated that analysis with letters from legal counsel, when appropriate, regarding cost recoveries or future changes in rates. We also assessed the methodology, accuracy and completeness of the Company’s calculations of regulatory asset and liability balances based on provisions and formulas outlined in rate orders and other correspondence with the regulators. We evaluated the Company’s disclosures related to the impacts of rate regulation. 

 

    Fair value measurement and disclosure of derivative financial instruments
Key Audit Matter  

Held-for-trading (“HFT”) derivative assets of $152 million and liabilities of $359 million, disclosed in note 15 to the consolidated financial statements, are measured at fair value. The Company recognized $200 million in realized and unrealized gains during the year with respect to HFT derivatives.

 

Auditing the Company’s valuation of HFT derivatives is complex and highly judgmental due to the complexity of the contract terms and valuation models, and the significant estimation required in determining the fair value of the contracts. In determining the fair value of HFT derivatives, significant assumptions about future economic and market assumptions with uncertain outcomes are used, including third-party sourced forward commodity pricing curves based on illiquid markets, internally developed correlation factors and basis differentials, the Company’s own credit risk and discount rates. These assumptions have a significant impact on the fair value of the HFT derivatives. 

     
How Our Audit Addressed the Key Audit Matter  

We performed audit procedures that included, amongst others, reviewing executed contracts and agreements for the identification of inputs and assumptions impacting the valuation of derivatives. With the support of our valuation specialists, we assessed the methodology and mathematical accuracy of the Company’s valuation models and compared the commodity pricing curves, credit metrics and discount rates used by the Company to current market and economic data. For the forward commodity pricing curves, we compared the Company’s pricing curves to independently sourced pricing curves. We also assessed the methodology and mathematical accuracy of the Company’s calculations to develop correlation factors and basis differentials. In addition, we assessed whether the fair value hierarchy disclosures in note 16 to the consolidated financial statements were consistent with the source of the significant inputs and assumptions used in determining the fair value of derivatives. 

 

Other information 

Management is responsible for the other information. The other information comprises:

 

Management’s Discussion and Analysis

The information, other than the consolidated financial statements and our auditor’s reports thereon, in the Annual Report

 

Our opinion on the consolidated financial statements does not cover the other information and we do not express any form of assurance conclusion thereon.

 

In connection with our audit of the consolidated financial statements, our responsibility is to read the other information, and in doing so, consider whether the other information is materially inconsistent with the consolidated financial statements or our knowledge obtained in the audit or otherwise appears to be materially misstated.

 

EMERA 2020 ANNUAL REPORT 75


 

INDEPENDENT AUDITOR’S REPORT

 

We obtained Management’s Discussion & Analysis prior to the date of this auditor’s report. If, based on the work we have performed, we conclude that there is a material misstatement of this other information, we are required to report that fact. We have nothing to report in this regard.

 

The Annual Report is expected to be made available to us after the date of the auditor’s report. If based on the work we will perform on this other information, we conclude there is a material misstatement of other information, we are required to report that fact to those charged with governance.

 

Responsibilities of management and those charged with governance for the consolidated financial statements Management is responsible for the preparation and fair presentation of the consolidated financial statements in accordance with USGAAP, and for such internal control as management determines is necessary to enable the preparation of consolidated financial statements that are free from material misstatement, whether due to fraud or error.

 

In preparing the consolidated financial statements, management is responsible for assessing the Company’s ability to continue as a going concern, disclosing, as applicable, matters related to going concern and using the going concern basis of accounting unless management either intends to liquidate the Company or to cease operations, or has no realistic alternative but to do so.

 

Those charged with governance are responsible for overseeing the Company’s financial reporting process.

 

Auditor’s responsibilities for the audit of the consolidated financial statements

Our objectives are to obtain reasonable assurance about whether the consolidated financial statements as a whole are free from material misstatement, whether due to fraud or error, and to issue an auditor’s report that includes our opinion. Reasonable assurance is a high level of assurance, but is not a guarantee that an audit conducted in accordance with Canadian generally accepted auditing standards will always detect a material misstatement when it exists. Misstatements can arise from fraud or error and are considered material if, individually or in the aggregate, they could reasonably be expected to influence the economic decisions of users taken on the basis of these consolidated financial statements.

 

As part of an audit in accordance with Canadian generally accepted auditing standards, we exercise professional judgment and maintain professional skepticism throughout the audit. We also:

 

Identify and assess the risks of material misstatement of the consolidated financial statements, whether due to fraud or error, design and perform audit procedures responsive to those risks, and obtain audit evidence that is sufficient and appropriate to provide a basis for our opinion. The risk of not detecting a material misstatement resulting from fraud is higher than for one resulting from error, as fraud may involve collusion, forgery, intentional omissions, misrepresentations, or the override of internal control.
Obtain an understanding of internal control relevant to the audit in order to design audit procedures that are appropriate in the circumstances, but not for the purpose of expressing an opinion on the effectiveness of the Company’s internal control.

Evaluate the appropriateness of accounting policies used and the reasonableness of accounting estimates and related disclosures made by management.

Conclude on the appropriateness of management’s use of the going concern basis of accounting and, based on the audit evidence obtained, whether a material uncertainty exists related to events or conditions that may cast significant doubt on the Company’s ability to continue as a going concern. If we conclude that a material uncertainty exists, we are required to draw attention in our auditor’s report to the related disclosures in the consolidated financial statements or, if such disclosures are inadequate, to modify our opinion. Our conclusions are based on the audit evidence obtained up to the date of our auditor’s report. However, future events or conditions may cause the Company to cease to continue as a going concern.

Evaluate the overall presentation, structure and content of the consolidated financial statements, including the disclosures, and whether the consolidated financial statements represent the underlying transactions and events in a manner that achieves fair presentation.

Obtain sufficient appropriate audit evidence regarding the financial information of the entities or business activities within the Company to express an opinion on the consolidated financial statements. We are responsible for the direction, supervision and performance of the group audit. We remain solely responsible for our audit opinion.

 

76 EMERA 2020 ANNUAL REPORT


 

INDEPENDENT AUDITOR’S REPORT

 

We communicate with those charged with governance regarding, among other matters, the planned scope and timing of the audit and significant audit findings, including any significant deficiencies in internal control that we identify during our audit.

 

We also provide those charged with governance with a statement that we have complied with relevant ethical requirements regarding independence, and to communicate with them all relationships and other matters that may reasonably be thought to bear on our independence, and where applicable, related safeguards.

 

From the matters communicated with those charged with governance, we determine those matters that were of most significance in the audit of the consolidated financial statements of the current period and are therefore the key audit matters. We describe these matters in our auditor’s report unless law or regulation precludes public disclosure about the matter or when, in extremely rare circumstances, we determine that a matter should not be communicated in our report because the adverse consequences of doing so would reasonably be expected to outweigh the public interest benefits of such communication.

 

The engagement partner on the audit resulting in this independent auditor’s report is Ivan Chittenden.

 

(GRAPHIC)
 
Chartered Professional Accountants
 
Halifax, Canada
February 16, 2021

 

EMERA 2020 ANNUAL REPORT 77


 

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

 

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

 

To the Shareholders and the Board of Directors of Emera Incorporated

 

Opinion on the Consolidated Financial Statements 

We have audited the accompanying Consolidated Balance Sheets of Emera Incorporated (the “Company”) as of December 31, 2020 and 2019, the related Consolidated Statements of Income, Consolidated Statements of Comprehensive Income, Consolidated Statements of Changes in Equity and Consolidated Statements of Cash Flows for the years then ended, and the related notes and schedules (collectively referred to as the “consolidated financial statements“). In our opinion, the consolidated financial statements present fairly, in all material respects, the consolidated financial position of the Company as of December 31, 2020 and 2019, and the consolidated results of its operations and its consolidated cash flows for each of the two years in the period ended December 31, 2020, in conformity with United States generally accepted accounting principles.

 

Basis for Opinion 

These consolidated financial statements are the responsibility of the Company‘s management. Our responsibility is to express an opinion on the Company‘s consolidated financial statements based on our audits. We are a public accounting firm registered with the Public Company Accounting Oversight Board (United States) (“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 audits to obtain reasonable assurance about whether the consolidated financial statements are free of material misstatement, whether due to error or fraud. The Company is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. As part of our audits we are required to obtain an understanding of internal control over financial reporting but not for the purpose of expressing an opinion on the effectiveness of the Company’s internal control over financial reporting. Accordingly, we express no such opinion.

 

Our audits included performing procedures to assess the risks of material misstatement of the consolidated 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 consolidated 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 consolidated financial statements. We believe that our audits provide a reasonable basis for our opinion.

 

78 EMERA 2020 ANNUAL REPORT


 

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

 

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 consolidated 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.

 

    Accounting for the effects of rate regulation
Description of the Matter   As disclosed in note 7 of the consolidated financial statements, the Company has $1.6 billion in regulatory assets and $2.0 billion in regulatory liabilities. The Company’s rate-regulated subsidiaries are subject to regulation by various federal, state and provincial regulatory authorities in the geographic regions in which they operate. The regulatory rates are designed to recover the prudently incurred costs of providing the regulated products or services and provide a reasonable return on the equity invested or assets, as applicable. In addition to regulatory assets and liabilities, rate regulation impacts multiple financial statement line items, including property, plant and equipment, operating revenues and expenses, income taxes, and depreciation expense.
     
    Auditing the impact of rate regulation on the Company’s financial statements is complex and highly judgmental due to the significant judgments made by the Company to support its accounting and disclosure for regulatory matters when final regulatory decisions or orders have not yet been obtained or when regulatory formulas are complex. There is also subjectivity involved in assessing the potential impact of future regulatory decisions on the financial statements. Although the Company expects to recover costs from customers through rates, there is a risk that the regulator will not approve full recovery of the costs incurred. The Company’s judgments include making an assessment of the probability of recovery of and recovery on costs incurred, of the disallowance of part of the cost of recently completed property, plant and equipment and construction work in progress, or of the probable refund to customers through future rates.
     
How We Addressed the Matter in Our Audit   We performed audit procedures that included, amongst others, assessing the Company’s evaluation of the probability of future recovery for regulatory assets, property, plant and equipment, and refund of regulatory liabilities by obtaining and reviewing relevant regulatory orders, filings, testimony, hearings and correspondence, and other publicly available information. For regulatory matters for which regulatory decisions or orders have not yet been obtained, we inspected the rate-regulated subsidiaries’ filings for any evidence that might contradict the Company’s assertions, and reviewed other regulatory orders, filings and correspondence for other entities within the same or similar jurisdictions to assess the likelihood of recovery in future rates based on the regulator’s treatment of similar costs under similar circumstances. We obtained and evaluated an analysis from the Company and corroborated that analysis with letters from legal counsel, when appropriate, regarding cost recoveries or future changes in rates. We also assessed the methodology, accuracy and completeness of the Company’s calculations of regulatory asset and liability balances based on provisions and formulas outlined in rate orders and other correspondence with the regulators. We evaluated the Company’s disclosures related to the impacts of rate regulation.

 

EMERA 2020 ANNUAL REPORT 79


 

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

 

    Fair value measurement and disclosure of derivative financial instruments
Description of the Matter   Held-for-trading (“HFT”) derivative assets of $152 million and liabilities of $359 million, disclosed in note 15 to the consolidated financial statements, are measured at fair value. The Company recognized $200 million in realized and unrealized gains during the year with respect to HFT derivatives.
     
    Auditing the Company’s valuation of HFT derivatives is complex and highly judgmental due to the complexity of the contract terms and valuation models, and the significant estimation required in determining the fair value of the contracts. In determining the fair value of HFT derivatives, significant assumptions about future economic and market assumptions with uncertain outcomes are used, including third-party sourced forward commodity pricing curves based on illiquid markets, internally developed correlation factors and basis differentials, the Company’s own credit risk and discount rates. These assumptions have a significant impact on the fair value of the HFT derivatives.
     
How We Addressed the Matter in Our Audit   We performed audit procedures that included, amongst others, reviewing executed contracts and agreements for the identification of inputs and assumptions impacting the valuation of derivatives. With the support of our valuation specialists, we assessed the methodology and mathematical accuracy of the Company’s valuation models and compared the commodity pricing curves, credit metrics and discount rates used by the Company to current market and economic data. For the forward commodity pricing curves, we compared the Company’s pricing curves to independently sourced pricing curves. We also assessed the methodology and mathematical accuracy of the Company’s calculations to develop correlation factors and basis differentials. In addition, we assessed whether the fair value hierarchy disclosures in note 16 to the consolidated financial statements were consistent with the source of the significant inputs and assumptions used in determining the fair value of derivatives.

 

 

 

Chartered Professional Accountants

 

We have served as the Company‘s auditor since 1998.

 

Halifax, Canada

February 16, 2021

 

80 EMERA 2020 ANNUAL REPORT


 

CONSOLIDATED FINANCIAL STATEMENTS

 

Emera Incorporated

CONSOLIDATED STATEMENTS OF INCOME

 

For the   Year ended December 31  
millions of Canadian dollars (except per share amounts)   2020     2019  
Operating revenues                
Regulated electric   $ 4,442     $ 4,769  
Regulated gas     1,034       1,081  
Non-regulated     30       261  
Total operating revenues (note 6)     5,506       6,111  
Operating expenses                
Regulated fuel for generation and purchased power (notes 17 and 19)     1,420       1,609  
Regulated cost of natural gas     293       350  
Non-regulated fuel for generation and purchased power     4       66  
Operating, maintenance and general     1,419       1,464  
Provincial, state, and municipal taxes     317       342  
Depreciation and amortization     881       903  
Impairment charges     25       34  
Total operating expenses     4,359       4,768  
Income from operations     1,147       1,343  
Income from equity investments (note 8)     149       154  
Other income, net (note 9)     708       12  
Interest expense, net     679       738  
Income before provision for income taxes     1,325       771  
Income tax expense (note 10)     341       61  
Net income     984       710  
Non-controlling interest in subsidiaries     1       2  
Preferred stock dividends     45       45  
Net income attributable to common shareholders   $ 938     $ 663  
                 
Weighted average shares of common stock outstanding (in millions) (note 12)                
Basic     248       240  
Diluted     248       240  
Earnings per common share (note 12 )                
Basic   $ 3.78     $ 2.76  
Diluted   $ 3.78     $ 2.76  
Dividends per common share declared   $ 2.4750     $ 2.3750  

 

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

 

EMERA 2020 ANNUAL REPORT 81


 

CONSOLIDATED FINANCIAL STATEMENTS

 

Emera Incorporated

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

 

For the   Year ended December 31  
millions of Canadian dollars   2020     2019  
Net income   $ 984     $ 710  
Other comprehensive income (loss), net of tax                
Foreign currency translation adjustment (1)     (201 )     (402 )
Unrealized gains on net investment hedges (2) (3)     26       78  
Cash flow hedges                
Net derivative gains           3  
Less: reclassification adjustment for losses included in income     2       3  
Net effects of cash flow hedges     2       6  
Net change in unrecognized pension and post-retirement benefit obligation (4)     (1 )     74  
Other comprehensive income (loss) (5)     (174 )     (244 )
Comprehensive income (loss)     810       466  
Comprehensive income (loss) attributable to non-controlling interest     1       1  
Comprehensive Income (loss) of Emera Incorporated   $ 809     $ 465  

 

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

 

(1) Net of tax recovery of $1 million (2019 – nil) for the year ended December 31, 2020.

(2) The Company has designated $1.2 billion United States dollar denominated Hybrid Notes as a hedge of the foreign currency exposure of its net investment in United States dollar denominated operations.

(3) Net of tax expense of $4 million (2019 – $1 million tax expense) for the year ended December 31, 2020.

(4) Net of tax recovery of $1 million (2019 – $9 million expense) for the year ended December 31, 2020.

(5) Net of tax expense of $2 million (2019 – $10 million expense) for the year ended December 31, 2020.

 

82 EMERA 2020 ANNUAL REPORT


 

CONSOLIDATED FINANCIAL STATEMENTS

 

Emera Incorporated

CONSOLIDATED BALANCE SHEETS

 

As at   December 31     December 31  
millions of Canadian dollars   2020     2019  
Assets                
Current assets                
Cash and cash equivalents   $ 220     $ 222  
Restricted cash (note 32)     34       51  
Inventory (note 14)     453       467  
Derivative instruments (notes 15 and 16)     73       54  
Regulatory assets (note 7)     165       121  
Receivables and other current assets (note 18)     1,233       1,486  
Assets held for sale (note 4)           85  
      2,178       2,486  
Property, plant and equipment, net of accumulated depreciation                
and amortization of $8,714 and $8,317, respectively (note 20)     19,535       18,167  
Other assets                
Deferred income taxes (note 10)     209       186  
Derivative instruments (notes 15 and 16)     25       33  
Regulatory assets (note 7)     1,419       1,431  
Net investment in direct financing lease (note 19)     475       473  
Investments subject to significant influence (note 8)     1,346       1,312  
Goodwill (note 22)     5,720       5,835  
Other long-term assets     327       300  
Assets held for sale (note 4)           1,619  
      9,521       11,189  
Total assets   $ 31,234     $ 31,842  

 

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

 

EMERA 2020 ANNUAL REPORT 83


 

CONSOLIDATED FINANCIAL STATEMENTS

 

Emera Incorporated

CONSOLIDATED BALANCE SHEETS (continued)

 

As at   December 31     December 31  
millions of Canadian dollars   2020     2019  
Liabilities and Equity                
Current liabilities                
Short-term debt (note 23)   $ 1,625     $ 1,537  
Current portion of long-term debt (note 25)     1,382       501  
Accounts payable     1,148       1,118  
Derivative instruments (notes 15 and 16)     251       268  
Regulatory liabilities (note 7)     129       295  
Other current liabilities (note 24)     340       333  
Liabilities associated with assets held for sale (note 4)           114  
      4,875       4,166  
Long-term liabilities                
Long-term debt (note 25)     12,339       13,679  
Deferred income taxes (note 10)     1,629       1,285  
Derivative instruments (notes 15 and 16)     87       102  
Regulatory liabilities (note 7)     1,832       1,886  
Pension and post-retirement liabilities (note 21)     453       460  
Other long-term liabilities (notes 8 and 26)     781       764  
Long-term liabilities associated with assets held for sale (note 4)           899  
      17,121       19,075  
Equity                
Common stock (note 11)     6,705       6,216  
Cumulative preferred stock (note 28)     1,004       1,004  
Contributed surplus     79       78  
Accumulated other comprehensive income (loss) (note 13)     (79 )     95  
Retained earnings     1,495       1,173  
Total Emera Incorporated equity     9,204       8,566  
Non-controlling interest in subsidiaries (note 29)     34       35  
Total equity     9,238       8,601  
Total liabilities and equity   $ 31,234     $ 31,842  

 

Commitments and contingencies (note 27)

 

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

 

Approved on behalf of the Board of Directors

 

   
   
“M. Jacqueline Sheppard” “Scott Balfour”
Chair of the Board President and Chief Executive Officer

 

84 EMERA 2020 ANNUAL REPORT


 

CONSOLIDATED FINANCIAL STATEMENTS

 

Emera Incorporated

CONSOLIDATED STATEMENTS OF CASH FLOWS

 

For the     Year ended December 31  
millions of Canadian dollars     2020     2019  
Operating activities              
Net income   $ 984   $ 710  
Adjustments to reconcile net income to net cash provided by operating activities:              
Depreciation and amortization     899     911  
Income from equity investments, net of dividends     (76 )   (83 )
Allowance for equity funds used during construction     (45 )   (21 )
Deferred income taxes, net     381     125  
Net change in pension and post-retirement liabilities     (23 )   (17 )
Regulated fuel adjustment mechanism     (94 )   (46 )
Net change in fair value of derivative instruments     (36 )   (39 )
Net change in regulatory assets and liabilities     (87 )   44  
Net change in capitalized transportation capacity     52     (55 )
Impairment charges     25     34  
Gain on sale, excluding transaction costs     (603 )    
Other operating activities, net     43     35  
Changes in non-cash working capital (note 30)     217     (73 )
Net cash provided by operating activities     1,637     1,525  
Investing activities              
Additions to property, plant and equipment     (2,623 )   (2,495 )
Proceeds from dispositions (note 4)     1,401     875  
Other investing activities     (2 )   3  
Net cash used in investing activities     (1,224 )   (1,617 )
Financing activities              
Change in short-term debt, net     385     413  
Proceeds from short-term debt with maturities greater than 90 days     399      
Repayment of short-term debt with maturities greater than 90 days     (688 )    
Proceeds from long-term debt, net of issuance costs     428     1,066  
Retirement of long-term debt     (513 )   (1,103 )
Net repayments under committed credit facilities     (203 )   (118 )
Issuance of common stock, net of issuance costs     285     203  
Dividends on common stock     (409 )   (378 )
Dividends on preferred stock     (45 )   (45 )
Other financing activities     (11 )   (24 )
Net cash (used in) provided by financing activities     (372 )   14  
Effect of exchange rate changes on cash, cash equivalents, and restricted cash     (61 )   (20 )
Net decrease in cash, cash equivalents, restricted cash and assets held for sale     (20 )   (98 )
Cash, cash equivalents, restricted cash, and assets held for sale, beginning of year     274     372  
Cash, cash equivalents, and restricted cash, end of year   $ 254   $ 274  
Cash, cash equivalents, restricted cash and assets held for sale consists of:              
Cash   $ 220   $ 222  
Restricted cash     34     51  
Assets held for sale         1  
Cash, cash equivalents and restricted cash   $ 254   $ 274  

 

Supplementary Information to Consolidated Statements of Cash Flows (note 30 )

 

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

 

EMERA 2020 ANNUAL REPORT 85


 

CONSOLIDATED FINANCIAL STATEMENTS

 

Emera Incorporated

CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY

 

     

Common
Stock 

   

Preferred

Stock

    Contributed Surplus    

Accumulated Other Comprehensive Income
(Loss)

(1)  

Retained Earnings

   

Non-
Controlling Interest

    Total Equity  
millions of Canadian dollars                                            
Balance, December 31, 2019   $ 6,216   $ 1,004   $ 78   $ 95   $ 1,173   $ 35   $ 8,601  
Net income of Emera incorporated                     983     1     984  
Other comprehensive loss, net of tax expense of $2 million                 (174 )           (174 )
Dividends declared on preferred stock (note 28)                     (45 )       (45 )
Dividends declared on common stock ($2.4750/share)                     (609 )       (609 )
Common stock issued under purchase plan     215                         215  
Issuance of common stock, net of after-tax issuance costs     251                         251  
Senior management stock options exercised     20         (1 )               19  
Adoption of credit losses accounting standard (note 2)                     (7 )       (7 )
Other     3         2             (2 )   3  
Balance, December 31, 2020   $ 6,705   $ 1,004   $ 79   $ (79 ) $ 1,495   $ 34   $ 9,238  
                                             
Balance, December 31, 2018   $ 5,816   $ 1,004   $ 84   $ 338   $ 1,075   $ 41   $ 8,358  
Net income                     708     2     710  
Other comprehensive loss, net of tax expense of $10 million                 (243 )       (1 )   (244 )
Dividends declared on preferred stock (note 28)                     (45 )       (45 )
Dividends declared on common stock ($2.3750/share)                     (565 )       (565 )
Common stock issued under purchase plan     195                         195  
Issuance of common stock, net of after-tax issuance costs     99                         99  
Senior management stock options exercised     104         (7 )               97  
Issuance of preferred shares of GBPC, net of issuance costs (note 29)                         14     14  
Redemption of preferred shares of GBPC (note 29)                         (19 )   (19 )
Other     2         1             (2 )   1  
Balance, December 31, 2019   $ 6,216   $ 1,004   $ 78   $ 95   $ 1,173   $ 35   $ 8,601  

(1) Accumulated Other Comprehensive Income (Loss) (“AOCI”) (“AOCL”).

 

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

 

86 EMERA 2020 ANNUAL REPORT


 

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

Emera Incorporated

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

As at December 31, 2020 and 2019

 

1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

 

NATURE OF OPERATIONS

Emera Incorporated (“Emera” or the “Company”) is an energy and services company which invests in electricity generation, transmission and distribution, and gas transmission and distribution.

 

At December 31, 2020, Emera’s reportable segments include the following:

 

Florida Electric Utility, which consists of Tampa Electric, a vertically integrated regulated electric utility, serving approximately 792,500 customers in West Central Florida;
Canadian Electric Utilities, which includes:
Nova Scotia Power Inc. (“NSPI”), a vertically integrated regulated electric utility and the primary electricity supplier in Nova Scotia, serving approximately 529,000 customers; and
Emera Newfoundland & Labrador Holdings Inc. (“ENL”), consisting of two transmission investments related to an 824 megawatt (“MW”) hydroelectric generating facility at Muskrat Falls on the Lower Churchill River in Labrador being developed by Nalcor Energy. ENL’s two investments are:
a 100 per cent investment in NSP Maritime Link Inc. (“NSPML”), which developed the Maritime Link Project, a $1.6 billion transmission project, including two 170-kilometre sub-sea cables, connecting the island of Newfoundland and Nova Scotia. This project went in service on January 15, 2018; and
a 45.6 per cent investment in the partnership capital of Labrador-Island Link Limited Partnership (“LIL”), a $3.7 billion electricity transmission project in Newfoundland and Labrador to enable the transmission of Muskrat Falls energy between Labrador and the island of Newfoundland. Construction of the LIL has been completed and Nalcor recognized the first flow of energy from Labrador to Newfoundland in June 2018. Nalcor continues to work towards commissioning the LIL. In response to the COVID-19 pandemic, on March 17, 2020 Nalcor announced that it had paused construction activities at the Muskrat Falls site and resumed work in May 2020. Nalcor achieved first power on the first of four generators at Muskrat Falls on September 22, 2020 and continues to work toward completing project commissioning in 2021. Refer to note 27 for further details.
Other Electric Utilities, which includes Emera (Caribbean) Incorporated (“ECI”), a holding company with regulated electric utilities that include:
The Barbados Light & Power Company Limited (“BLPC”), a vertically integrated regulated electric utility on the island of Barbados, serving approximately 131,000 customers;
Grand Bahama Power Company Limited (“GBPC”), a vertically integrated regulated electric utility on Grand Bahama Island, serving approximately 19,000 customers;
a 51.9 per cent interest in Dominica Electricity Services Ltd. (“Domlec”), a vertically integrated regulated electric utility on the island of Dominica, serving approximately 34,000 customers; and
a 19.5 per cent equity interest in St. Lucia Electricity Services Limited (“Lucelec”), a vertically integrated regulated electric utility on the island of St. Lucia.

 

EMERA 2020 ANNUAL REPORT 87


 

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

On March 24, 2020, Emera completed the sale of Emera Maine which was previously included in the Other Electric Utilities segment. Refer to note 4 for further information.

 

Gas Utilities and Infrastructure, which includes:
Peoples Gas System (“PGS”), a regulated gas distribution utility, serving approximately 426,000 customers across Florida;
New Mexico Gas Company, Inc. (“NMGC”), a regulated gas distribution utility, serving approximately 540,000 customers in New Mexico;
SeaCoast Gas Transmission, LLC (“SeaCoast”), a regulated intrastate natural gas transmission company offering services in Florida;
Emera Brunswick Pipeline Company Limited (“Brunswick Pipeline”), a 145-kilometre pipeline delivering re-gasified liquefied natural gas (“LNG”) from Saint John, New Brunswick to the United States border under a 25-year firm service agreement with Repsol Energy Canada, which expires in 2034; and
a 12.9 per cent interest in Maritimes & Northeast Pipeline (“M&NP”), a 1,400-kilometre pipeline, which transports natural gas throughout markets in Atlantic Canada and the northeastern United States.

 

Emera’s other reportable segment includes investments in energy-related non-regulated companies which includes:
Emera Energy, which consists of:
Emera Energy Services (“EES”), a physical energy business that purchases and sells natural gas and electricity and provides related energy asset management services;
Brooklyn Power Corporation (“Brooklyn Energy”), a 30 MW biomass co-generation electricity facility in Brooklyn, Nova Scotia; and
a 50.0 per cent joint venture interest in Bear Swamp Power Company LLC (“Bear Swamp”), a 600 MW pumped storage hydroelectric facility in northwestern Massachusetts.
Emera Reinsurance Limited, a captive insurance company providing insurance and reinsurance to Emera and certain affiliates, to enable more cost-efficient management of risk and deductible levels across Emera;
Emera US Finance LP (“Emera Finance”) and TECO Finance, Inc. (“TECO Finance”), financing subsidiaries of Emera;
Emera US Holdings Inc., a wholly owned holding company for certain of Emera’s assets located in the United States; and
other investments.

 

In 2019, the Company completed the sale of assets previously included in the Other segment, including Emera Energy’s New England Gas Generating (“NEGG”) and Bayside facilities, and Emera Utility Services (“EUS”) equipment and inventory.

 

In 2020, the outbreak of the novel strain of coronavirus, specifically identified as COVID-19, has resulted in governments worldwide enacting emergency measures to combat the spread of the virus. While management considered the impact of COVID-19 in the Company’s estimates and results, the financial statements as of and for the year ended December 31, 2020 were not materially impacted by COVID-19. However, it is not possible to reliably estimate the length and severity of the COVID-19 pandemic and the impact on the financial results and condition of the Company in future periods.

 

BASIS OF PRESENTATION

These consolidated financial statements are prepared and presented in accordance with United States Generally Accepted Accounting Principles (“USGAAP”). In the opinion of management, these consolidated financial statements include all adjustments that are of a recurring nature and necessary to fairly state the financial position of Emera.

 

All dollar amounts are presented in Canadian dollars, unless otherwise indicated.

 

PRINCIPLES OF CONSOLIDATION

The consolidated financial statements of Emera include the accounts of Emera Incorporated, its majority-owned subsidiaries, and a variable interest entity (“VIE”) in which Emera is the primary beneficiary. Refer to note 32 for further details. Emera uses the equity method of accounting to record investments in which the Company has the ability to exercise significant influence, and for variable interest entities in which Emera is not the primary beneficiary.

 

88 EMERA 2020 ANNUAL REPORT


 

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

The Company performs ongoing analysis to assess whether it holds any VIEs or whether any reconsideration events have arisen with respect to existing VIEs. To identify potential VIEs, management reviews contractual and ownership arrangements such as leases, long-term purchase power agreements, tolling contracts, guarantees, jointly owned facilities and equity investments. VIEs of which the Company is deemed the primary beneficiary must be consolidated. The primary beneficiary of a VIE has both the power to direct the activities of the entity that most significantly impact its economic performance and the obligation to absorb losses of the entity that could potentially be significant to the entity. In circumstances where Emera has an investment in a VIE but is not deemed the primary beneficiary, the VIE is accounted for using the equity method.

 

Intercompany balances and transactions have been eliminated on consolidation, except for the net profit on certain transactions between certain non-regulated and regulated entities in accordance with accounting standards for rate-regulated entities. The net profit on these transactions, which would be eliminated in the absence of the accounting standards for rate-regulated entities, is recorded in non-regulated operating revenues. An offset is recorded to property, plant and equipment, regulatory assets, regulated fuel for generation and purchased power, or operating, maintenance and general (“OM&G”), depending on the nature of the transaction.

 

USE OF MANAGEMENT ESTIMATES

The preparation of consolidated financial statements in accordance with USGAAP requires management to make estimates and assumptions. These may affect the reported amounts of assets and liabilities at the date of the financial statements and reported amounts of revenues and expenses during the reporting periods. Significant areas requiring the use of management estimates relate to rate-regulated assets and liabilities, allowance for credit losses, accumulated reserve for cost of removal, pension and post-retirement benefits, unbilled revenue, useful lives for depreciable assets, goodwill and long-lived assets impairment assessments, income taxes, asset retirement obligations, and valuation of financial instruments. Management evaluates the Company’s estimates on an ongoing basis based upon historical experience, current and expected conditions and assumptions believed to be reasonable at the time the assumption is made, with any adjustments recognized in income in the year they arise.

 

During the year ended December 31, 2020, the ongoing COVID-19 pandemic has affected all service territories in which Emera operates. The pandemic has generally resulted in lower load and higher operating costs than what otherwise would have been experienced at the Company’s utilities. Some of Emera’s utilities have been impacted more than others. However, on a consolidated basis these unfavourable impacts have not had a material financial impact to net earnings primarily due to a favourable change to the mix of sales across customer classes. Lower commercial and industrial sales have been partially offset by increased sales to residential customers, which have a higher contribution to fixed cost recovery. Favourable weather in 2020, particular in Florida, has further reduced the consolidated impact. Emera’s utilities provide essential services and continue to operate and meet customer demand. Governments world-wide have implemented measures intended to address the pandemic. These measures include travel and transportation restrictions, quarantines, physical distancing, closures of commercial spaces and industrial facilities, shutdowns, shelter-in-place orders and other health measures. These measures are adversely impacting global, national and local economies. Global equity markets have experienced significant volatility. Governments and central banks are implementing measures designed to stabilize economic conditions. The pace and strength of economic recovery is uncertain and may vary among jurisdictions.

 

Management has analyzed the impact of the COVID-19 pandemic on its estimates and assumptions and concluded that no material adjustments are required for the year ended December 31, 2020. Refer to Asset Impairment: Long-Lived Assets, Asset Impairment: Goodwill and Employee Benefits below for additional details on area’s that could be more significantly impacted.

 

The extent of future impact of COVID-19 on the Company’s financial results and business operations cannot be predicted at this time and will depend on future developments, including the duration and severity of the pandemic, timing and effectiveness of vaccinations, further potential government actions and future economic activity and energy usage. Actual results may differ significantly from these estimates.

 

REGULATORY MATTERS

Regulatory accounting applies where rates are established by, or subject to approval by, an independent third-party regulator. The rates are designed to recover prudently incurred costs of providing the regulated products or services and provide an opportunity for a reasonable rate of return on the equity invested or assets, as applicable (refer to note 7 for additional details).

 

EMERA 2020 ANNUAL REPORT 89


 

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

FOREIGN CURRENCY TRANSLATION

Monetary assets and liabilities denominated in foreign currencies are converted to Canadian dollars at the rates of exchange prevailing at the balance sheet date. The resulting differences between the translation at the original transaction date and the balance sheet date are included in income.

 

Assets and liabilities of foreign operations whose functional currency is not the Canadian dollar are translated using the exchange rates in effect at the balance sheet date and the results of operations at the average exchange rate in effect for the period. The resulting exchange gains and losses on the assets and liabilities are deferred on the balance sheet in AOCI.

 

The Company designates certain United States dollar denominated debt held in Canadian dollar functional currency companies as hedges of net investments in United States dollar denominated foreign operations. The change in the carrying amount of these investments, measured at the exchange rates in effect at the balance sheet date is recorded in Other Comprehensive Income (“OCI”).

 

REVENUE RECOGNITION

 

Regulated Electric Revenue

Electric revenues, including energy charges, demand charges, basic facilities charges and clauses and riders, are recognized when obligations under the terms of a contract are satisfied, which is when electricity is delivered to customers over time as the customer simultaneously receives and consumes the benefits of the electricity. Electric revenues are recognized on an accrual basis and include billed and unbilled revenues. Revenues related to the sale of electricity are recognized at rates approved by the respective regulator and recorded based on metered usage, which occurs on a periodic, systematic basis, generally monthly or bi-monthly. At the end of each reporting period, the electricity delivered to customers, but not billed, is estimated and the corresponding unbilled revenue is recognized. The Company’s estimate of unbilled revenue at the end of the reporting period is calculated by estimating the number of megawatt hour (“MWh”) delivered to customers at the established rate expected to prevail in the upcoming billing cycle. This estimate includes assumptions as to the pattern of energy demand, weather, line losses and inter-period changes to customer classes.

 

Regulated Gas Revenue

Gas revenues, including energy charges, demand charges, basic facilities charges and applicable clauses and riders, are recognized when obligations under the terms of a contract are satisfied, which is when gas is delivered to customers over time as the customer simultaneously receives and consumes the benefits of the gas. Gas revenues are recognized on an accrual basis and include billed and unbilled revenues. Revenues related to the distribution and sale of gas are recognized at rates approved by the respective regulator and recorded based on metered usage, which occurs on a periodic, systematic basis, generally monthly. At the end of each reporting period, the gas delivered to customers, but not billed, is estimated and the corresponding unbilled revenue is recognized. The Company’s estimate of unbilled revenue at the end of the reporting period is calculated by estimating the number of therms delivered to customers at the established rate expected to prevail in the upcoming billing cycle. This estimate includes assumptions as to the pattern of usage, weather, and inter-period changes to customer classes.

 

Non-regulated Revenue

Marketing and trading margins are comprised of Emera Energy’s corresponding purchases and sales of natural gas and electricity, pipeline capacity costs and energy asset management revenues. Revenues are recorded when obligations under terms of a contract are satisfied and are presented on a net basis, reflecting the nature of the contractual relationships with customers and suppliers.

 

Energy sales are recognized when obligations under the terms of the contracts are satisfied, which is when electricity is delivered to customers over time.

 

Capacity payments are recognized when obligations under the terms of a contract are satisfied, which is as the plants stand ready to deliver electricity to customers. Revenues related to capacity payments are recognized at rates determined through an auction process held annually, three years in advance, through the forward capacity market.

 

Other non-regulated revenues are recorded when obligations under terms of a contract are satisfied.

 

90 EMERA 2020 ANNUAL REPORT


 

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

Other

 

Sales, value add, and other taxes, except for gross receipts taxes discussed below, collected by the Company concurrent with revenue-producing activities are excluded from revenue.

 

LEASES

The Company determines whether a contract contains a lease at inception by evaluating if the contract conveys the right to control the use of an identified asset for a period of time in exchange for consideration.

 

Emera has leases with independent power producers and other utilities with annual requirements to purchase wind and hydro energy over varying contract lengths that are classified as finance leases. These finance leases are not recorded on the Company’s Consolidated Balance Sheets as payments associated with the leases are variable in nature and there are no minimum fixed lease payments. Lease expense associated with these leases is recorded as “Regulated fuel for generation and purchased power” on the Consolidated Statements of Income.

 

Operating lease liabilities and right-of-use (“ROU”) assets are recognized on the Consolidated Balance Sheets based on the present value of the future minimum lease payments over the lease term at commencement date. As most of Emera’s leases do not provide an implicit rate, the incremental borrowing rate at commencement of the lease is used in determining the present value of future lease payments. Lease expense is recognized on a straight-line basis over the lease term and is recorded as “Operating, maintenance and general” on the Consolidated Statements of Income.

 

Where the Company is the lessor, a lease is a sales-type lease if certain criteria are met and the arrangement transfers control of the underlying asset to the lessee. For arrangements where the criteria are met due to the presence of a third-party residual value guarantee, the lease is a direct financing lease.

 

For direct finance leases, a net investment in the lease is recorded that consists of the sum of the minimum lease payments and residual value (net of estimated executory costs and unearned income). The difference between the gross investment and the cost of the leased item is recorded as unearned income at the inception of the lease. Unearned income is recognized in income over the life of the lease using a constant rate of interest equal to the internal rate of return on the lease.

 

For sales-type leases, the accounting is similar to the accounting for direct finance leases, however the difference between the fair value and the carrying value of the leased item is recorded at lease commencement rather than deferred over the term of the lease.

 

Emera has certain contractual agreements that include lease and non-lease components, which management has elected to account for as a single lease component.

 

FRANCHISE FEES AND GROSS RECEIPTS

Tampa Electric and PGS recover from customers certain costs incurred, on a dollar-for-dollar basis, through prices approved by the Florida Public Service Commission (“FPSC”). The amounts included in customers’ bills for franchise fees and gross receipt taxes are included as “Regulated electric” and “Regulated gas” revenues in the Consolidated Statements of Income. Franchise fees and gross receipt taxes payable by Tampa Electric and PGS are included as an expense on the Consolidated Statements of Income in “Provincial, state and municipal taxes”.

 

NMGC is an agent in the collection and payment of franchise fees and gross receipt taxes and is not required by a tariff to present the amounts on a gross basis. Therefore, NMGC’s franchise fees and gross receipt taxes are presented net with no line item impact on the Consolidated Statements of Income.

 

EMERA 2020 ANNUAL REPORT 91


 

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

PROPERTY, PLANT AND EQUIPMENT

Property, plant and equipment are recorded at original cost, including allowance for funds used during construction (“AFUDC”) or capitalized interest, net of contributions received in aid of construction.

 

The cost of additions, including betterments and replacements of units of property, plant and equipment are included in “Property, plant and equipment”. When units of regulated property, plant and equipment are replaced, renewed or retired, their cost plus removal or disposal costs, less salvage proceeds, is charged to accumulated depreciation, with no gain or loss reflected in income. Where a disposition of non-regulated property, plant and equipment occurs, gains and losses are included in income as the dispositions occur.

 

The cost of property, plant and equipment represents the original cost of materials, contracted services, direct labour, AFUDC for regulated property or interest for non-regulated property, asset retirement obligations (“ARO”) and overhead attributable to the capital project. Overhead includes corporate costs such as finance, information technology and labour costs, along with other costs related to support functions, employee benefits, insurance, procurement, and fleet operating and maintenance. Expenditures for project development are capitalized if they are expected to have a future economic benefit.

 

Normal maintenance projects are expensed as incurred. Planned major maintenance projects that do not increase the overall life of the related assets are expensed. When a major maintenance project increases the life or value of the underlying asset, the cost is capitalized.

 

Depreciation is determined by the straight-line method, based on the estimated remaining service lives of the depreciable assets in each functional class of depreciable property. For some of Emera’s rate-regulated subsidiaries depreciation is calculated using the group remaining life method, which is applied to the average investment, adjusted for anticipated costs of removal less salvage, in functional classes of depreciable property. The service lives of regulated assets require the appropriate regulatory approval.

 

Intangible assets, which are included in “Property, plant and equipment” consist primarily of computer software and land rights. Amortization is determined by the straight-line method, based on the estimated remaining service lives of the asset in each category. For some of Emera’s rate-regulated subsidiaries, amortization is calculated using the amortizable life method which is applied to the net book value to date over the remaining life of those assets. The service lives of regulated intangible assets require regulatory approval.

 

GOODWILL

Goodwill is calculated as the excess of the purchase price of an acquired entity over the estimated fair values of identifiable assets acquired and liabilities assumed at the acquisition date. Goodwill is carried at initial cost less any write-down for impairment and is adjusted for the impact of foreign exchange. Under the applicable accounting guidance, goodwill is subject to assessment for impairment at the reporting unit level annually or if an event or change in circumstances indicates that the fair value of a reporting unit may be below its carrying value. Refer to note 22 for further detail.

 

INCOME TAXES AND INVESTMENT TAX CREDITS

Emera recognizes deferred income tax assets and liabilities for the future tax consequences of events that have been included in the financial statements or income tax returns. Deferred income tax assets and liabilities are determined based on the difference between the carrying value of assets and liabilities on the Consolidated Balance Sheets and their respective tax bases using enacted tax rates in effect for the year in which the differences are expected to reverse. The effect of a change in income tax rates on deferred income tax assets and liabilities is recognized in earnings in the period when the change is enacted unless required to be offset to a regulatory asset or liability by law or by order of the regulator. Emera recognizes the effect of income tax positions only when it is more likely than not that they will be realized. Management reviews all readily available current and historical information, including forward-looking information, and the likelihood that deferred tax assets will be recovered from future taxable income is assessed and assumptions about the expected timing of the reversal of deferred tax assets and liabilities are made. If management subsequently determines that it is likely that some or all of a deferred income tax asset will not be realized, then a valuation allowance is recorded to reflect the amount of deferred income tax asset expected to be realized.

 

92 EMERA 2020 ANNUAL REPORT


 

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

Generally, investment tax credits are recorded as a reduction to income tax expense in the current or future periods to the extent that realization of such benefit is more likely than not. Investment tax credits earned by Tampa Electric, PGS and NMGC on regulated assets are deferred and amortized over the estimated service lives of the related properties, as required by regulatory practices.

 

Tampa Electric, PGS, NMGC, BLPC and Domlec collect income taxes from customers based on current and deferred income taxes. NSPI, ENL and Brunswick Pipeline collect income taxes from customers based on income tax that is currently payable except for the deferred income taxes on certain regulatory balances specifically prescribed by the regulator. For the balance of regulated deferred income taxes, NSPI, ENL and Brunswick Pipeline recognize regulatory assets or liabilities where the deferred income taxes are expected to be recovered from or returned to customers in future years. These regulated assets or liabilities are grossed up using the respective income tax rate to reflect the income tax associated with future revenues that are required to fund these deferred income tax liabilities, and the income tax benefits associated with reduced revenues resulting from the realization of deferred income tax assets. GBPC is not subject to income taxes.

 

Emera classifies interest and penalties associated with unrecognized tax benefits as interest and operating expense, respectively. Refer to note 10 for further details.

 

DERIVATIVES AND HEDGING ACTIVITIES

The Company manages its exposure to normal operating and market risks relating to commodity prices, foreign exchange, interest rates and share prices through contractual protections with counterparties where practicable, and by using financial instruments consisting mainly of foreign exchange forwards and swaps, interest rate options and swaps, equity derivatives, and coal, oil and gas futures, options, forwards and swaps. In addition, the Company has contracts for the physical purchase and sale of natural gas. These physical and financial contracts are classified as held-for-trading (“HFT”). Collectively, these contracts and financial instruments are considered derivatives.

 

The Company recognizes the fair value of all its derivatives on its balance sheet, except for non-financial derivatives that meet the normal purchases and normal sales (“NPNS”) exception. A physical contract generally qualifies for the NPNS exception if the transaction is reasonable in relation to the Company’s business needs, the counterparty owns or controls resources within the proximity to allow for physical delivery, the Company intends to receive physical delivery of the commodity, and the Company deems the counterparty creditworthy. Emera continually assesses contracts designated under the NPNS exception and will discontinue the treatment of these contracts under this exemption where the criteria are no longer met.

 

Derivatives qualify for hedge accounting if they meet stringent documentation requirements and can be proven to effectively hedge the identified risk both at the inception and over the term of the instrument. Specifically, for cash flow hedges, the change in the fair value of derivatives is deferred to AOCI and recognized in income in the same period the related hedged item is realized. Where the documentation or effectiveness requirements are not met any changes in fair value are recognized in net income in the reporting period, unless deferred as a result of regulatory accounting.

 

Derivatives entered into by NMGC, NSPI and GBPC that are documented as economic hedges, and for which the NPNS exception has not been taken, are subject to regulatory accounting treatment. The change in fair value of the derivatives is deferred to a regulatory asset or liability. The gain or loss is recognized in the hedged item when the hedged item is settled. Management believes any gains or losses resulting from settlement of these derivatives related to fuel for generation and purchased power will be refunded to or collected from customers in future rates. Tampa Electric and PGS have no derivatives related to hedging as a result of a Florida Public Service Commission approved five-year moratorium on hedging of natural gas purchases which ends on December 31, 2022.

 

Derivatives that do not meet any of the above criteria are designated as HFT, with changes in fair value normally recorded in net income of the period. The Company has not elected to designate any derivatives to be included in the HFT category where another accounting treatment would apply.

 

Emera classifies gains and losses on derivatives as a component of fuel for generation and purchased power, other expenses, inventory and property, operating maintenance and general and plant and equipment, depending on the nature of the item being economically hedged. Transportation capacity arising as a result of marketing and trading derivative transactions is recognized as an asset in “Receivables and other current assets” and amortized over the period of the transportation contract term. Cash flows from derivative activities are presented in the same category as the item being hedged within operating or investing activities on the Consolidated Statements of Cash Flows. Non-hedged derivatives are included in operating cash flows on the Consolidated Statements of Cash Flows.

 

EMERA 2020 ANNUAL REPORT 93


 

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

Derivatives, as reflected on the Consolidated Balance Sheets, are not offset by the fair value amounts of cash collateral with the same counterparty. Rights to reclaim cash collateral are recognized in “Receivables and other current assets” and obligations to return cash collateral are recognized in “Accounts payable”.

 

CASH, CASH EQUIVALENTS AND RESTRICTED CASH

Cash equivalents consist of highly liquid short-term investments with original maturities of three months or less at acquisition.

 

RECEIVABLES AND ALLOWANCE FOR CREDIT LOSSES

Utility customer receivables are recorded at the invoiced amount and do not bear interest. Standard payment terms for electricity and gas sales are approximately 30 days. A late payment fee may be assessed on account balances after the due date.

 

The Company is exposed to credit risk with respect to amounts receivable from customers. Credit assessments may be conducted on new customers. Deposits are requested on accounts in accordance with the Company’s policy. The Company also maintains provisions for expected credit losses, which are assessed on a regular basis.

 

Management estimates credit losses related to accounts receivable after considering historical loss experience, customer deposits, current events, the characteristics of existing accounts and reasonable and supportable forecasts that affect the collectability of the reported amount. Provisions for credit losses on receivables are expensed to maintain the allowance at a level considered adequate to cover expected losses. Receivables are written off against the allowance when they are deemed uncollectible.

 

The economic impact of COVID-19, in the service territories in which Emera operates, has impacted the aging of customer receivables resulting in higher allowances for credit losses related to customer receivables however it has not had a material impact on earnings.

 

INVENTORY

Fuel and materials inventories are valued using the weighted-average cost method. These inventories are carried at the lower of weighted-average cost or net realizable value, unless evidence indicates that the weighted-average cost will be recovered in future customer rates.

 

ASSET IMPAIRMENT

 

Long-Lived Assets

Emera assesses whether there has been an impairment of long-lived assets and intangibles when a triggering event occurs, such as a significant market disruption or sale of a business.

 

The review of long-lived assets for impairment involves comparing the undiscounted expected future cash flows to the carrying value of the asset. When the undiscounted cash flow analysis indicates a long-lived asset is not recoverable, the amount of the impairment loss is determined by measuring the excess of the carrying amount of the long-lived asset over its estimated fair value. The Company’s assumptions relating to future results of operations or other recoverable amounts are based on a combination of historical experience, fundamental economic analysis, observable market activity and independent market studies. The Company’s expectations regarding uses and holding periods of assets are based on internal long-term budgets and projections, which give consideration to external factors and market forces, as of the end of each reporting period. The assumptions made are consistent with generally accepted industry approaches and assumptions used for valuation and pricing activities.

 

Management considered whether the potential impacts of the COVID-19 pandemic on undiscounted future cash flows could indicate that long-lived assets are not recoverable. As at December 31, 2020, there are no indications of impairment of Emera’s long-lived assets. The impact of COVID-19 could cause the Company to impair long-lived assets in the future; however, there is currently no indication that future cash flows would be impacted to a point where the Company’s long-lived assets would not be recoverable.

 

Impairment charges of $25 million ($26 million after tax) were recognized on certain assets during the year ended December 31, 2020 and recorded in Impairment Charge in the Consolidated Income Statement. In 2019, as a result of Hurricane Dorian, Grand Bahama recognized an impairment of $18 million USD which has been fully recovered through insurance.

 

94 EMERA 2020 ANNUAL REPORT


 

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

Goodwill

Goodwill is not amortized but is subject to an annual assessment for impairment at the reporting unit level with interim impairment tests performed when impairment indicators are present. Reporting units are generally determined at the operating segment level or one level below the operating segment level. Reporting units with similar characteristics are grouped for the purpose of determining impairment, if any, of goodwill. When assessing goodwill for impairment the Company has the option of first performing a qualitative assessment to determine whether a quantitative assessment is necessary. In performing a qualitative assessment management considers, among other factors, macroeconomic conditions, industry and market considerations and overall financial performance.

 

If the Company performs the qualitative assessment and determines that it is more likely than not that its fair value is less than its carrying amount or if the Company chooses to bypass the qualitative assessment, a quantitative test is performed. The quantitative test compares the fair value of the reporting unit to its carrying amount, including goodwill. If the carrying amount of the reporting unit exceeds its fair value, an impairment loss is recorded as a reduction to goodwill and a charge to operating expense. Management estimates the fair value of the reporting unit by using the income approach or a combination of the income and market approach. The income approach is applied using a discounted cash flow analysis which relies on management’s best estimate of the reporting units’ projected cash flows. The analysis includes an estimate of terminal values based on these expected cash flows using a methodology which derives a valuation using an assumed perpetual annuity based on the reporting unit’s residual cash flows. The discount rate used is a market participant rate based on a peer group of publicly traded comparable companies and represents the weighted average cost of capital of comparable companies. When using the market approach, management estimates fair value based on comparable companies and transactions within the utility industry. Significant assumptions used in estimating the fair value include discount and growth rates, rate case assumptions, valuation of the reporting unit’s net operating loss (“NOL”), utility sector market performance and transactions, projected operating and capital cash flows and the fair value of debt. Adverse changes in assumptions described above could result in a future material impairment of the goodwill assigned to Emera’s reporting units with goodwill. As part of the 2020 goodwill impairment assessment management considered the potential impacts of the COVID-19 pandemic on the future earnings of the reporting units.

 

As of December 31, 2020, $5,649 million of Emera’s goodwill was related to TECO Energy (Tampa Electric, PGS and NMGC reporting units). Qualitative assessments were performed for these reporting units given the significant excess of fair value over carrying amounts calculated during the last quantitative test in Q4 2019. Management concluded that it was more likely than not that the fair value of these reporting units exceeded their respective carrying amounts, including goodwill. As such, no quantitative testing was required.

 

A GBPC goodwill impairment charge of $30 million was recorded in 2019 due to a decrease in expected future cash flows resulting from the impacts of Hurricane Dorian storm recovery and changes in the anticipated long term regulated capital structure of GBPC. As of December 31, 2020, $68 million of Emera’s goodwill was related to GBPC. In Q4 2020, the Company performed a quantitative impairment assessment for GBPC as this reporting unit is more sensitive to changes in forecasted future earnings due to limited excess of fair value over the carrying value. The assessment estimated that the fair value of the reporting unit exceeded its carrying value, including goodwill, by approximately five per cent. Adverse changes in significant assumptions could result in a future impairment. Refer to note 22 for further details.

 

Equity Method Investments

The carrying value of investments accounted for under the equity method are assessed for impairment by comparing the fair value of these investments to their carrying values, if a fair value assessment was completed, or by reviewing for the presence of impairment indicators, including the impact of COVID-19. If an impairment exists and it is determined to be other-than-temporary, a charge is recognized in earnings equal to the amount the carrying value exceeds the investment’s fair value. No impairment of equity method investments was required for either 2019 or 2020.

 

Financial Assets

Equity investments, other than those accounted for under the equity method of accounting, are measured at fair value with changes in fair value recognized in the Consolidated Statements of Income. Equity investments that do not have readily determinable fair values are recorded at cost minus impairment, if any, plus or minus changes resulting from observable price changes in orderly transactions for the identical or similar investments. No impairment of financial assets was required for either 2019 or 2020.

 

EMERA 2020 ANNUAL REPORT 95


 

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

ASSET RETIREMENT OBLIGATIONS

An ARO is recognized if a legal obligation exists in connection with the future disposal or removal costs resulting from the permanent retirement, abandonment or sale of a long-lived asset. A legal obligation may exist under an existing or enacted law or statute, written or oral contract, or by legal construction under the doctrine of promissory estoppel.

 

An ARO represents the fair value of the estimated cash flows necessary to discharge the future obligation using the Company’s credit adjusted risk-free rate. The amounts are reduced by actual expenditures incurred. Estimated future cash flows are based on completed depreciation studies, remediation reports, prior experience, estimated useful lives and governmental regulatory requirements. The present value of the liability is recorded and the carrying amount of the related long-lived asset is correspondingly increased. The amount capitalized at inception is depreciated in the same manner as the related long-lived asset. Over time, the liability is accreted to its estimated future value. AROs are included in “Other long-term liabilities” and accretion expense is included as part of “Depreciation and amortization”. Any regulated accretion expense not yet approved by the regulator is recorded in “Property, plant and equipment” and included in the next depreciation study.

 

Some of the Company’s transmission and distribution assets may have conditional ARO’s which are not recognized in the consolidated financial statements as the fair value of these obligations could not be reasonably estimated, given there is insufficient information to do so. A conditional ARO refers to a legal obligation to perform an asset retirement activity in which the timing and/or method of settlement are conditional on a future event that may or may not be within the control of the entity. Management monitors these obligations and a liability is recognized at fair value in the period in which an amount can be determined.

 

COST OF REMOVAL

Tampa Electric, PGS, NMGC and NSPI recognize non-ARO costs of removal (“COR”) as regulatory liabilities. The non-ARO costs of removal represent funds received from customers through depreciation rates to cover estimated future non-legally required cost of removal of property, plant and equipment upon retirement. The companies accrue for removal costs over the life of the related assets based on depreciation studies approved by their respective regulators. The costs are estimated based on historical experience and future expectations, including expected timing and estimated future cash outlays.

 

STOCK-BASED COMPENSATION

The Company has several stock-based compensation plans: a common share option plan for senior management; an employee common share purchase plan; a deferred share unit (“DSU”) plan; a performance share unit (“PSU”) plan; and a restricted share unit (“RSU”) plan. The Company accounts for its plans in accordance with the fair value based method of accounting for stock-based compensation. Stock-based compensation cost is measured at the grant date, based on the calculated fair value of the award, and is recognized as an expense over the employee’s or director’s requisite service period using the graded vesting method. Stock-based compensation plans recognized as liabilities are initially measured at fair value and re-measured at fair value at each reporting date with the change in liability recognized in income.

 

EMPLOYEE BENEFITS

The costs of the Company’s pension and other post-retirement benefit programs for employees are expensed over the periods during which employees render service. The Company recognizes the funded status of its defined-benefit and other post-retirement plans on the balance sheet and recognizes changes in funded status in the year the change occurs. The Company recognizes the unamortized gains and losses and past service costs in AOCI or regulatory assets. The components of net periodic benefit cost other than the service cost component are included in “Other income (expense), net” on the Consolidated Statements of Income.

 

The COVID-19 pandemic could impact key actuarial assumptions used to account for employee post-retirement benefits including the anticipated rates of return on plan assets and discount rates used in determining the accrued benefit obligation, benefit costs and annual pension funding requirements.

 

96 EMERA 2020 ANNUAL REPORT


 

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

2. CHANGE IN ACCOUNTING POLICY

 

The new USGAAP accounting policies that are applicable to, and adopted by the Company in 2020, are described as follows:

 

MEASUREMENT OF CREDIT LOSSES ON FINANCIAL INSTRUMENTS

The Company adopted Accounting Standard Update (“ASU”) 2016-13, Measurement of Credit Losses on Financial Instruments effective January 1, 2020. The standard provides guidance regarding the measurement of credit losses for financial assets and certain other instruments that are not accounted for at fair value through net income. These include trade and other receivables, debt securities, net investment in leases, and off-balance sheet credit exposures. The new guidance requires companies to replace the current incurred loss impairment methodology with a methodology that measures all expected credit losses for financial assets based on historical experience, current conditions, and reasonable and supportable forecasts. The guidance expands the disclosure requirements regarding credit losses, including the credit loss methodology and credit quality indicators. The adoption of the standard resulted in a $7 million decrease to retained earnings in the consolidated financial statements as of January 1, 2020.

 

SIMPLIFYING THE ACCOUNTING FOR INCOME TAXES

In December 2019, the FASB issued ASU 2019-12, Simplifying the Accounting for Income Taxes. The standard simplifies the accounting for income taxes by eliminating certain exceptions to the guidance in ASC 740 related to the approach for intraperiod tax allocation. It also simplifies aspects of accounting for franchise taxes and enacted changes in tax laws or rates and clarifies the accounting for transactions that result in a step-up in the tax basis of goodwill. The guidance is effective for annual reporting periods, including interim reporting within those periods, beginning after December 15, 2020, with early adoption permitted. The standard is applied on both a prospective and retrospective basis. The Company early adopted the standard effective January 1, 2020. There was no impact on the consolidated financial statements as a result of the adoption of this standard.

 

FACILITATION OF THE EFFECTS OF REFERENCE RATE REFORM ON FINANCIAL REPORTING

The Company adopted ASU 2020-04, Reference Rate Reform (Topic 848): Facilitation of the Effects of Reference Rate Reform on Financial Reporting in Q4 2020. The standard provides options and exceptions for applying USGAAP to contract modifications and hedging relationships that reference the London Inter-Bank Offered Rate (“LIBOR”) or any other reference rate that is expected to be discontinued. The guidance was effective as of the date of issuance and entities may elect to apply the guidance prospectively through December 31, 2022. The Company’s transition from reference rates will not have a material impact on the consolidated financial statements. In November 2020, the Federal Reserve extended the phase-out of LIBOR until June 2023. The Company will continue to monitor the impact this may have on application of the standard.

 

EMERA 2020 ANNUAL REPORT 97


 

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

3. FUTURE ACCOUNTING PRONOUNCEMENTS

 

The Company considers the applicability and impact of all ASUs issued by the FASB. The following updates have been issued by the FASB, but as allowed, have not yet been adopted by Emera. Any ASUs not included below were assessed and determined to be either not applicable to the Company or have an insignificant impact on the consolidated financial statements.

 

ACCOUNTING FOR CONVERTIBLE INSTRUMENTS AND CONTRACTS IN AN ENTITY’S OWN EQUITY

In August 2020, the FASB issued ASU 2020-06, Debt – Debt with Conversion and Other Options (Subtopic 470-20) and Derivatives and Hedging – Contracts in Entity’s Own Equity (Subtopic 815-40). The standard simplifies the accounting for convertible debenture debt instruments and convertible preferred stock, in addition to amending disclosure requirements. The standard also updates guidance for the derivative scope exception for contracts in an entity’s own equity and the related earnings per share guidance. The guidance will be effective for annual reporting periods, including interim reporting within those periods, beginning after December 15, 2021. Early adoption is permitted, but no earlier than fiscal years beginning after December 15, 2020. The standard can be applied through either a modified retrospective method of transition or a fully retrospective method of transition. The Company early adopted the standard effective January 1, 2021 using the modified retrospective method. There was no material impact on the consolidated financial statements as a result of the adoption of this standard.

 

GUARANTEED DEBT SECURITIES DISCLOSURE REQUIREMENTS

In October 2020, the FASB issued ASU 2020-09, Debt (Topic 470): Amendments to SEC Paragraphs pursuant to SEC Release No. 33-10762. The change in the standard aligns with new SEC rules relating to changes to the disclosure requirements for certain registered debt securities that are guaranteed. The changes include simplifying disclosure, enhancing certain narrative disclosures and permitting the disclosures to be made outside of the financial statements. The guidance will be effective for annual reports filed for fiscal years ending after January 4, 2021, with early adoption permitted. The Company is currently evaluating the impact of adoption of the standard on its consolidated financial statements.

 

4. DISPOSITIONS

 

On March 24, 2020, Emera completed the sale of Emera Maine for a total enterprise value of approximately $2.0 billion including cash proceeds of $1.4 billion, transferred debt and working capital adjustments. A gain on disposition of $585 million ($309 million after tax) net of transaction costs, was recognized in the Other segment and included in “Other income” on the Consolidated Statements of Income.

 

Emera Maine’s assets and liabilities were classified as held for sale at March 25, 2019. The Company continued recording depreciation on these assets through the transaction closing date, as the depreciation continued to be reflected in customer rates and was reflected in the carryover basis of the assets on completion of the sale. A total of $53 million of depreciation and amortization was recorded on these assets from March 25, 2019, the date they were classified as held for sale, until the date of the sale. $39 million of the $53 million was recorded in 2019. Emera Maine’s assets and liabilities were included in the Company’s Other Electric Utilities segment.

 

98 EMERA 2020 ANNUAL REPORT


 

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

5. SEGMENT INFORMATION

 

Emera manages its reportable segments separately due in part to their different operating, regulatory and geographical environments. Segments are reported based on each subsidiary’s contribution of revenues, net income attributable to common shareholders and total assets, as reported to the Company’s chief operating decision maker. Emera’s five reportable segments are Florida Electric Utility, Canadian Electric Utilities, Other Electric Utilities, Gas Utilities and Infrastructure, and Other.

 

millions of Canadian dollars   Florida
Electric
Utility
  Canadian
Electric
Utilities
  Other
Electric
Utilities
  Gas Utilities
and

Infrastructure
  Other   Inter-
segment
Eliminations
  Total  
For the year ended December 31, 2020
Operating revenues from external customers (1)   $ 2,473   $ 1,494   $ 474   $ 1,051   $ 14   $   $ 5,506  
Inter-segment revenues (1)     7             7     15     (29 )    
Total operating revenues     2,480     1,494     474     1,058     29     (29 )   5,506  
Regulated fuel for generation and purchased power     574     659     194             (7 )   1,420  
Regulated cost of natural gas                 293             293  
OM&G     552     282     151     334     115     (15 )   1,419  
Depreciation and amortization     455     236     71     111     8         881  
Income from equity investments         96     4     20     29         149  
AFUDC – debt and equity     54     4     1     9             68  
Interest expense, net     151     139     32     56     301         679  
Internally allocated interest (2)                 13     (13 )        
Gain on sale, net of transactions costs                     585         585  
Impairment charges                     (25 )       (25 )
Income tax expense (recovery)     89     17     (8 )   51     192         341  
Net income (loss) attributable to common shareholders     501     221     35     162     19         938  
Capital expenditures     1,361     338     148     749     4         2,600  
As at December 31, 2020                                            
Total assets     16,889     6,752     1,365     6,067     1,234     (1,073 )(3)   31,234  
Investments subject to significant influence         1,176     41     129             1,346  
Goodwill     4,455         68     1,194     3         5,720  
(1) All significant inter-company balances and inter-company transactions have been eliminated on consolidation except for certain transactions between non-regulated and regulated entities that have not been eliminated because management believes the elimination of these transactions would understate property, plant and equipment, OM&G expenses, or regulated fuel for generation and purchased power. Inter-company transactions that have not been eliminated are measured at the amount of consideration established and agreed to by the related parties. Eliminated transactions are included in determining reportable segments.
(2) Segment net income is reported on a basis that includes internally allocated financing costs.
(3) Primarily relates to consolidated deferred tax reclassifications. Deferred tax assets are reclassified and netted with deferred tax liabilities upon consolidation.

 

EMERA 2020 ANNUAL REPORT 99


 

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

millions of Canadian dollars   Florida
Electric
Utility
  Canadian
Electric
Utilities
  Other
Electric
Utilities
  Gas Utilities
and

Infrastructure
  Other   Inter-
segment
Eliminations
  Total  
For the year ended December 31, 2019
Operating revenues from external customers (1)   $ 2,596   $ 1,429   $ 744   $ 1,097   $ 245   $   $ 6,111  
Inter-segment revenues (1)     11     1         22     37     (71 )    
Total operating revenues     2,607     1,430     744     1,119     282     (71 )   6,111  
Regulated fuel for generation and purchased power     772     573     286             (22 )   1,609  
Regulated cost of natural gas                 350             350  
OM&G     554     313     195     319     130     (47 )   1,464  
Depreciation and amortization     445     231     107     109     11         903  
Income from equity investments         91     5     22     36         154  
AFUDC – debt and equity     20     6     5     2             33  
Interest expense, net     154     142     52     59     331         738  
Internally allocated interest (2)                 14     (14 )        
Impairment charges             34                 34  
Income tax expense (recovery)     79     (10 )   11     48     (67 )       61  
Net income (loss) attributable to common shareholders     419     229     45     183     (213 )       663  
Capital expenditures     1,393     384     195     448     63         2,483  
As at December 31, 2019                                            
Total assets     16,214     6,717     3,069     5,489     1,459     (1,106) (3)   31,842  
Investments subject to significant influence         1,133     41     138             1,312  
Goodwill     4,544         70     1,218     3         5,835  
(1) All significant inter-company balances and inter-company transactions have been eliminated on consolidation except for certain transactions between non-regulated and regulated entities that have not been eliminated because management believes the elimination of these transactions would understate property, plant and equipment, OM&G expenses, or regulated fuel for generation and purchased power. Inter-company transactions that have not been eliminated are measured at the amount of consideration established and agreed to by the related parties. Eliminated transactions are included in determining reportable segments.
(2) Segment net income is reported on a basis that includes internally allocated financing costs.
(3) Primarily relates to consolidated deferred tax reclassifications. Deferred tax assets are reclassified and netted with deferred tax liabilities upon consolidation.

 

GEOGRAPHICAL INFORMATION

Revenues (1):

 

For the Year ended December 31  
millions of Canadian dollars   2020   2019  
Canada   $ 1,569   $ 1,497  
United States     3,522     4,140  
Barbados     263     320  
The Bahamas     112     112  
Dominica     40     42  
    $ 5,506   $ 6,111  
(1) Revenues are based on country of origin of the product or service sold.

 

100 EMERA 2020 ANNUAL REPORT


 

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

Property Plant and Equipment:

 

As at
millions of Canadian dollars
  December 31
2020
  December 31
2019
 
Canada   $ 4,304   $ 4,248  
United States     14,353     13,095  
Barbados     510     462  
The Bahamas     289     282  
Dominica     79     80  
    $ 19,535   $ 18,167  

 

6. REVENUE

 

The following disaggregates the Company’s revenue by major source:

 

millions of Canadian dollars   Florida
Electric
Utility
  Canadian
Electric
Utilities
  Other
Electric
Utilities
  Gas Utilities
and

Infrastructure
  Other   Inter-
segment
Eliminations
  Total  
For the year ended December 31, 2020
Regulated                                            
Electric Revenue                                            
Residential   $ 1,365   $ 806   $ 179   $   $   $   $ 2,350  
Commercial     678     405     233                 1,316  
Industrial     178     224     32                 434  
Other electric and regulatory deferrals     242     31     8                 281  
Other (1)     17     28     22     1         (7 )   61  
Regulated electric revenue     2,480     1,494     474     1         (7 )   4,442  
Gas Revenue                                            
Residential                 495             495  
Commercial                 275             275  
Industrial                 54             54  
Finance income (2) (3)                 61             61  
Other                 156         (7 )   149  
Regulated gas revenue                 1,041         (7 )   1,034  
Non-Regulated                                            
Marketing and trading margin (4)                     38         38  
Energy sales (4)                     16     (16 )    
Capacity                              
Other                 16     21         37  
Mark-to-market (3)                     (46 )   1     (45 )
Non-regulated revenue                 16     29     (15 )   30  
Total operating revenues   $ 2,480   $ 1,494   $ 474   $ 1,058   $ 29   $ (29 ) $ 5,506  
(1) Other includes rental revenues, which do not represent revenue from contracts with customers.
(2) Revenue related to Brunswick Pipeline’s service agreement with Repsol Energy Canada.
(3) Revenue which does not represent revenues from contracts with customers.
(4) Includes gains (losses) on settlement of energy related derivatives, which do not represent revenue from contracts with customers.

 

EMERA 2020 ANNUAL REPORT 101


 

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

millions of Canadian dollars   Florida
Electric
Utility
  Canadian
Electric
Utilities
  Other
Electric
Utilities
  Gas Utilities
and

Infrastructure
  Other   Inter-
segment
Eliminations
  Total  
For the year ended December 31, 2019
Regulated                                            
Electric Revenue                                            
Residential   $ 1,387   $ 746   $ 276   $   $   $   $ 2,409  
Commercial     745     400     339                 1,484  
Industrial     207     210     44                 461  
Other electric and regulatory deferrals     246     45     13                 304  
Other (1)     22     29     72             (12 )   111  
Regulated electric revenue     2,607     1,430     744             (12 )   4,769  
Gas Revenue                                            
Residential                 502             502  
Commercial                 298             298  
Industrial                 50             50  
Finance income (2) (3)                 60             60  
Other                 193         (22 )   171  
Regulated gas revenue                 1,103         (22 )   1,081  
Non-Regulated                                            
Marketing and trading margin (4)                     31         31  
Energy sales (4)                     80     (12 )   68  
Capacity                     38         38  
Other                 16     31     (25 )   22  
Mark-to-market (3)                     102         102  
Non-regulated revenue                 16     282     (37 )   261  
Total operating revenues   $ 2,607   $ 1,430   $ 744   $ 1,119   $ 282   $ (71 ) $ 6,111  
(1) Other includes rental revenues, which do not represent revenue from contracts with customers.
(2) Revenue related to Brunswick Pipeline’s service agreement with Repsol Energy Canada.
(3) Revenue which does not represent revenues from contracts with customers.
(4) Includes gains (losses) on settlement of energy related derivatives, which do not represent revenue from contracts with customers.

 

Remaining Performance Obligations

Remaining performance obligations primarily represent gas transportation contracts, lighting contracts and long-term steam supply arrangements with fixed contract terms. As of December 31, 2020, the aggregate amount of the transaction price allocated to remaining performance obligations was $464 million (2019 – $347 million). This amount includes $149 million of future performance obligations related to a gas transportation contract between SeaCoast and PGS through 2040. This amount excludes contracts with an original expected length of one year or less and variable amounts for which Emera recognizes revenue at the amount to which it has the right to invoice for services performed. Emera expects to recognize revenue for the remaining performance obligations through 2040.

 

102 EMERA 2020 ANNUAL REPORT


 

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

7. REGULATORY ASSETS AND LIABILITIES

 

Regulatory assets represent prudently incurred costs that have been deferred because it is probable they will be recovered through future rates or tolls collected from customers. Management believes existing regulatory assets are probable for recovery either because the Company received specific approval from the applicable regulator, or due to regulatory precedent established for similar circumstances. If management no longer considers it probable that an asset will be recovered, the deferred costs are charged to income.

 

Regulatory liabilities represent obligations to make refunds to customers or to reduce future revenues for previous collections. If management no longer considers it probable that a liability will be settled, the related amount is recognized in income.

 

For regulatory assets and liabilities that are amortized, the amortization is as approved by the respective regulator.

 

Regulatory Assets and Liabilities

 

As at
millions of Canadian dollars
December 31
 2020
December 31
 2019
Regulatory assets
Deferred income tax regulatory assets $ 887 $ 862
Pension and post-retirement medical plan 394 380
Deferrals related to derivative instruments 65 81
Cost recovery clauses 49 13
Storm restoration regulatory asset 41 38
Environmental remediations 28 26
Stranded cost recovery 26 27
Demand side management (“DSM”) deferral 15 19
Unamortized defeasance costs 13 19
Other 66 87
$ 1,584 $ 1,552
Current $ 165 $ 121
Long-term 1,419 1,431
Total regulatory assets $ 1,584 $ 1,552
Regulatory liabilities
Deferred income tax regulatory liabilities 933 985
Accumulated reserve – cost of removal 865 891
Storm reserve 62 62
Cost recovery clauses 31 53
Self-insurance fund (note 32) 28 29
Regulated fuel adjustment mechanism 21 115
Deferrals related to derivative instruments 15 42
Other 6 4
$ 1,961 $ 2,181
Current $ 129 $ 295
Long-term 1,832 1,886
Total regulatory liabilities $ 1,961 $ 2,181

 

Deferred Income Tax Regulatory Assets and Liabilities

To the extent deferred income taxes are expected to be recovered from or returned to customers in future years, a regulatory asset or liability is recognized as appropriate.

 

Pension and Post-Retirement Medical Plan

This asset is primarily related to the deferred costs of pension and post-retirement benefits at Tampa Electric, PGS and NMGC. It is included in rate base and earns a rate of return as permitted by the FPSC and New Mexico Public Regulation Commission (“NMPRC”) as applicable. It is amortized over the remaining service life of plan participants.

 

EMERA 2020 ANNUAL REPORT 103


 

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

Deferrals Related to Derivative Instruments

This asset is primarily related to NSPI deferring changes in fair value of derivatives that are documented as economic hedges or that do not qualify for NPNS exemption, as a regulatory asset or liability as approved by its regulator. The realized gain or loss is recognized when the hedged item settles in regulated fuel for generation and purchased power, inventory, operating, maintenance or general or property, plant and equipment, depending on the nature of the item being economically hedged.

 

Cost Recovery Clauses

These assets and liabilities are related to Tampa Electric, PGS and NMGC clauses and riders. They are recovered or refunded through cost-recovery mechanisms approved by the FPSC or NMPRC, as applicable, on a dollar-for-dollar basis in a subsequent period.

 

Storm Restoration Regulatory Asset

This asset represents storm restoration costs, primarily incurred by GBPC. GBPC maintains insurance for its generation facilities and, as with most utilities, its transmission and distribution networks are self-insured. On September 1, 2019, Hurricane Dorian struck Grand Bahama Island as a Category 5 hurricane, with sustained winds of approximately 285 kilometres per hour. The hurricane stalled over the island for several days, causing significant damage to, or destruction of, homes and businesses served by GBPC. GBPC’s generation, transmission and distribution assets sustained damage, including the effect of flooding that resulted from storm surge and rain.

 

In January 2020, the Grand Bahama Port Authority (“GBPA”) approved the recovery of $15 million USD of costs related to the storm over a five-year period. The recovery was implemented through rates on January 1, 2021.

 

Restoration costs associated with Hurricane Matthew in 2016 are being recovered through an approved fuel charge over a five-year period. Additional details on the recovery are included under the Grand Bahama Power Company Limited section below. The balance of the regulatory asset as at December 31, 2020 is $18 million USD.

 

Environmental Remediations

This asset is primarily related to PGS costs associated with environmental remediation at Manufactured Gas Plant sites. The balance is included in rate base, partially offsetting the related liability, and earns a rate of return as permitted by the FPSC. The timing of recovery is based on a settlement agreement approved by the FPSC.

 

Stranded Cost Recovery

Due to the decommissioning of a GBPC steam turbine in 2012, the GBPA approved the recovery of a $21 million USD stranded cost through electricity rates; it is included in rate base and is expected to be included in rates in future years.

 

DSM Deferral

The Nova Scotia Utility and Review Board (“UARB”) approved implementation of the 2015 DSM deferral set at $35 million in 2015 and recoverable from customers over an 8-year period beginning in 2016.

 

The UARB directed EfficiencyOne, a franchisee appointed by the Province of Nova Scotia to provide NSPI with electricity efficiency and conservation activities under the Public Utilities Act, to review financing options through which EfficiencyOne would borrow the 2015 deferral amount from a commercial lender in order to repay NSPI the amount it expended on behalf of its customers in 2015. In December 2016, EfficiencyOne secured financing and $31 million was advanced to NSPI to finance the 2015 DSM deferral. In February 2017, EfficiencyOne advanced an additional $2 million to NSPI. As NSPI collects the associated amounts from customers over the remaining three years, it will repay the balance to EfficiencyOne. This has been set up as a liability in “Other long-term liabilities” with the current portion of the liability included in “Other current liabilities” on the Consolidated Balance Sheets.

 

Unamortized Defeasance Costs

Upon privatization in 1992, NSPI became responsible for managing a portfolio of defeasance securities held in trust that provide the principal and interest streams to match the related defeased debt, which as at December 31, 2020, totalled $582 million (2019 – $740 million). The excess of the cost of defeasance investments over the face value of the related debt is deferred on the balance sheet and amortized over the life of the defeased debt as permitted by the UARB.

 

104 EMERA 2020 ANNUAL REPORT


 

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

Accumulated Reserve – Cost of Removal (“COR”)

This regulatory liability represents the non-ARO COR reserve in Tampa Electric, PGS, NMGC and NSPI. AROs are costs for legally required removal of property, plant and equipment. Non-ARO COR represent estimated funds received from customers through depreciation rates to cover future non-legally required cost of removal of property, plant and equipment, net of salvage value upon retirement, which reduces rate base for ratemaking purposes. This liability is reduced as COR are incurred and increased as depreciation is recorded for existing assets and as new assets are put into service.

 

Storm Reserve

The storm reserve is for hurricanes and other named storms that cause significant damage to Tampa Electric and PGS systems. As allowed by the FPSC, if the charges to the storm reserve exceed the storm liability, the excess is to be carried as a regulatory asset. Tampa Electric and PGS can petition the FPSC to seek recovery of restoration costs over a 12-month period, or longer, as determined by the FPSC, as well as replenish the reserve. In September 2019, Tampa Electric incurred approximately $8 million USD in storm restoration preparation costs for Hurricane Dorian. These costs were charged to the storm reserve regulatory liability.

 

Regulated Fuel Adjustment Mechanism

This regulated liability is the difference between actual fuel costs and amounts recovered from NSPI customers through electricity rates in a given year, and deferred to a fuel adjustment mechanism (“FAM”) regulatory asset or liability and recovered from or returned to customers in a subsequent year. As approved on December 6, 2019 as part of NSPI’s three-year Fuel Stability Plan, differences between actual fuel costs and fuel revenues recovered from customers for the years 2020 to 2022, will be recovered or returned to customers after 2022. The UARB’s decision to approve the Fuel Stability Plan directed that any annual non-fuel revenues above NSPI’s approved range of ROE are to be applied to the FAM.

 

REGULATORY ENVIRONMENTS

 

Florida Electric Utility

Tampa Electric is regulated by the FPSC. Tampa Electric is also subject to regulation by the Federal Energy Regulatory Commission (“FERC”). The FPSC sets rates at a level that allows utilities such as Tampa Electric to collect total revenues or revenue requirements equal to their cost of providing service, plus an appropriate return on invested capital.

 

Tampa Electric’s approved regulated return on equity (“ROE”) range for 2020 and 2019 is 9.25 per cent to 11.25 per cent based on an allowed equity capital structure of 54 per cent. An ROE of 10.25 per cent is used for the calculation of the return on investments for clauses.

 

Fuel Recovery

Tampa Electric has a fuel recovery clause approved by the FPSC, allowing the opportunity to recover fluctuating fuel expenses from customers through annual fuel rate adjustments. The FPSC annually approves cost-recovery rates for purchased power, capacity, environmental and conservation costs including a return on capital invested. Differences between the prudently incurred fuel costs and the cost-recovery rates and amounts recovered from customers through electricity rates in a year are deferred to a regulatory asset or liability and recovered from or returned to customers in a subsequent year.

 

Base Rates

On February 1, 2021, Tampa Electric notified the FPSC of its intent to seek a base rate increase, reflecting incremental revenue requirements of approximately $280 million USD to $295 million USD, effective January 2022. Tampa Electric’s proposed rates include recovery for the costs of the first phase of the Big Bend modernization project, 225 MW of utility-scale solar projects, the AMI investment, and accelerated recovery of the remaining net book value of retiring assets. Tampa Electric also intends to seek approval for Generation Base Rate Adjustments of $130 million USD to recover the costs of the second phase of the Big Bend modernization project and additional utility-scale solar projects in subsequent years. These filing amounts are estimates until Tampa Electric completes and files its detailed case. Tampa Electric expects to file its detailed case on or after April 2, 2021, and a decision by the FPSC is expected by the end of 2021.

 

On April 9, 2019, Tampa Electric reached a settlement agreement with consumer parties regarding eligible storm costs as a result of Hurricane Irma in 2017, which was approved by the FPSC on May 21, 2019. As a result, Tampa Electric refunded $12 million USD to customers in January 2020, resulting in minimal impact to the Consolidated Statements of Income.

 

EMERA 2020 ANNUAL REPORT 105


 

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

On August 20, 2018, the FPSC approved a reduction in base rates of $103 million USD annually beginning in 2019 as a result of lower tax expense due to 2018 US tax reform benefits.

 

Solar Base Rate Adjustments Included in Base Rates

As of December 31, 2020, Tampa Electric has invested $820 million USD in 600 MW of utility-scale solar photovoltaic projects, which are recoverable through FPSC-approved solar base rate adjustments (“SoBRAs”). Tampa Electric expects to invest an additional $30 million USD in these projects through 2021. AFUDC is being earned on these projects during construction. The FPSC has approved SoBRAs representing a total of 600 MW or $104 million USD annually in estimated revenue requirements for in-service projects.

 

The true-up filing for SoBRAs tranche 1 and 2 revenue requirement estimates that were included in base rates as of September 2018 and January 2019, respectively, was submitted on April 30, 2020, and the FPSC approved the amount on August 18, 2020. A $5 million USD true-up was returned to customers in 2020. The true-ups for SoBRA tranches 3 and 4 will be filed in 2021 and 2022, respectively.

 

Storm Protection Cost Recovery Clause and Settlement Agreement

On October 3, 2019, the FPSC issued a rule to implement a Storm Protection Plan (“SPP”) Cost Recovery Clause. This new clause provides a process for Florida investor-owned utilities, including Tampa Electric, to recover transmission and distribution storm hardening costs for incremental activities not already included in base rates. Tampa Electric submitted its storm protection plan with the FPSC on April 10, 2020. On April 27, 2020, Tampa Electric submitted a settlement agreement with the FPSC which specified a $15 million USD base rate reduction for SPP program costs previously recovered in base rates beginning January 1, 2021. On June 9, 2020, the FPSC approved this settlement agreement. On August 3, 2020, Tampa Electric submitted another settlement agreement to the FPSC for approval, including cost recovery of approximately $39 million USD in proposed storm protection project costs for 2020 and 2021. This cost recovery includes the $15 million USD of costs removed from base rates. This settlement agreement was approved on August 10, 2020 and Tampa Electric’s cost recovery began in January 2021. The current approved plan will apply for the years 2020, 2021 and 2022, and Tampa Electric will file a new plan in 2022 to determine cost recovery in 2023, 2024, and 2025.

 

The June 9, 2020 settlement agreement approved by the FPSC disclosed above also included approval of Tampa Electric’s petition to eliminate its $16 million USD accumulated amortization reserve surplus for intangible software assets through a credit to amortization expense in 2020.

 

Big Bend Modernization Project

Tampa Electric has invested approximately $526 million USD through December 31, 2020 to modernize the Big Bend Power Station. The modernization project will repower Big Bend Unit 1 with natural gas combined-cycle technology and eliminate coal as this unit’s fuel. On June 1, 2020, Tampa Electric retired the Unit 1 components that will not be used in the modernized plant. At June 1, 2020 and December 31, 2020, the balance sheet included $304 million ($223 million USD) and $255 million ($200 million USD) respectively, in electric utility plant and $123 million ($90 million USD) and $112 million ($88 million USD) respectively, in accumulated depreciation related to Unit 1 components. In accordance with Tampa Electric’s 2017 settlement agreement approved by the FPSC, Tampa Electric will continue to account for its existing investment in Unit 1 in electric utility plant and depreciate the assets using the current depreciation rates until the FPSC approves Tampa Electric’s next depreciation and dismantlement study. In addition, Tampa Electric plans to retire Big Bend Unit 2 in 2021. In accordance with Tampa Electric’s 2017 settlement agreement, Tampa Electric was not required to request an asset recovery schedule for retired assets until the next depreciation study. On December 30, 2020, Tampa Electric filed a depreciation and dismantlement study and request for capital recovery schedules with the FPSC.

 

Tampa Electric plans to retire Big Bend Unit 3 in 2023. Similar to the retirement plan for Unit 1 and Unit 2, Tampa Electric will continue to account for its existing investment in Unit 3 in electric utility plant and depreciate the assets using the current depreciation rates until the FPSC approves Tampa Electric’s next depreciation and dismantlement study.

 

106 EMERA 2020 ANNUAL REPORT


 

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

Canadian Electric Utilities

 

NSPI

NSPI is a public utility as defined in the Public Utilities Act of Nova Scotia (“Public Utilities Act”) and is subject to regulation under the Public Utilities Act by the UARB. The Public Utilities Act gives the UARB supervisory powers over NSPI’s operations and expenditures. Electricity rates for NSPI’s customers are also subject to UARB approval.

 

NSPI is regulated under a cost-of-service model, with rates set to recover prudently incurred costs of providing electricity service to customers and provide a reasonable return to investors. NSPI’s approved regulated ROE range for 2020 and 2019 was 8.75 per cent to 9.25 per cent based on an actual five quarter average regulated common equity component of up to 40 per cent.

 

NSPI has a FAM, approved by UARB which enables it to seek recovery of its fuel costs from customers through regularly scheduled fuel rate adjustments. Differences between actual fuel costs and amounts recovered from customers through electricity rates in a year are deferred to a FAM regulatory asset or liability and recovered from or returned to customers in a subsequent year.

 

NSPI is currently operating under a three-year fuel stability plan which results in an average annual overall rate increase of 1.5 per cent to recover fuel costs for the period of 2020 through 2022. These rates include recovery of Maritime Link costs.

 

The Maritime Link is a $1.6 billion transmission project including two 170-kilometre sub-sea cables, connecting the island of Newfoundland and Nova Scotia. The Maritime Link entered service on January 15, 2018 and NSPI started paying the UARB approved interim assessment payments to NSPML at that time. The UARB approved 2020 interim cost assessment recovery payment to NSPML was $145 million and as of December 31, 2020 $135 million has been paid. The payments were subject to a holdback of $10 million pending UARB agreement that a minimum of $10 million in benefits from the Maritime Link are realized for NSPI customers. If the $10 million in benefits is realized, the UARB will direct NSPI to pay the $10 million to NSPML for that year. If not realized, then the UARB will direct NSPI to pay to NSPML only that portion that is realized and the balance will be refunded to customers through NSPI’s FAM. For 2020, NSPI has recorded a $4 million holdback payable to NSPML.

 

On December 16, 2020, the UARB approved NSPML’s 2021 interim cost assessment recovery from NSPI of Maritime Link costs of approximately $172 million subject to a holdback of $10 million on similar terms as previously approved by the UARB. It also includes a potential long-term deferral of up to $23 million in depreciation expense dependent upon the timing of commencement of the Nova Scotia Block (“NS Block”). Refer to the NSPML section below for further detail.

 

As part of a three-year fuel stability plan, electricity rates have been set to include the $145 million approved Maritime Link assessment for 2020 and estimate amounts of $164 million and $162 million for 2021 and 2022, respectively. Any difference between the amounts included in the Fuel Stability Plan and those approved by the UARB through the NSPML interim assessment application will be addressed through the FAM.

 

In response to the delayed timing of energy delivery from the Muskrat Falls project, which is being developed by Nalcor Energy, the approved Maritime Link interim assessment payments reflected a reduction in NSPML’s assessment in each of 2018 and 2019, related to depreciation and amortization expenses. NSPI refunded the reduced 2018 NSPML assessment to customers in 2018 and 2019, by providing a credit to customers of $17 million and $35 million, respectively. The UARB’s decision to approve NSPI’s 2020-2022 fuel stability plan outlined the treatment of the reduced 2019 NSPML assessment of $52 million plus interest. The majority of the reduced assessment was refunded to most customers through a reduction incorporated into their 2020 rates and the remaining customers received a one-time on bill credit in 2020. As at December 31, 2020, $40 million plus interest has been refunded to customers, with the remaining $12 million plus interest to be returned to customers subsequent to 2022.

 

Pursuant to the FAM Plan of Administration, NSPI’s Fuel Costs are subject to independent audit. On August 21, 2020, the FAM audit results for 2018 and 2019 were filed with the UARB. A hearing was held in January 2021 and a decision is expected in Q2 2021.

 

On March 13, 2020, the UARB’s decision on the FAM audit findings and recommendations relating to fiscal 2016 and 2017 was released. The final recommendations did not include any disallowances.

 

EMERA 2020 ANNUAL REPORT 107


 

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

NSPML

Equity earnings contributions from the Maritime Link are dependent on the approved ROE and operational performance of NSPML. NSPML’s approved regulated ROE range is 8.75 per cent to 9.25 per cent, based on an actual five-quarter average regulated common equity component of up to 30 per cent.

 

On December 16, 2020 the UARB approved NSPML’s 2021 interim assessment for recovery of Maritime Link costs from NSPI of approximately $172 million (2020 – $145 million). This payment is subject to a holdback of $10 million on similar terms as previously approved by the UARB. Recovery of $115 million of operating and maintenance, debt financing and equity financing costs began on January 1, 2021. Recovery of $57 million of depreciation and amortization will commence the sooner of the delivery of the NS Block or May 1, 2021. With cooperation of the Government of Canada, NSPML may also utilize up to $23 million of cash in a debt related reserve account to reduce the recovery of costs from NSPI in 2021, depending upon when the NS Block commences. NSPML will file a final cost assessment with the UARB after the commencement of the NS Block which is anticipated to take place in 2021.

 

Other Electric Utilities

 

The Barbados Light & Power Company Limited

BLPC is regulated by the Fair Trading Commission (“FTC”), an independent regulator, under the Utilities Regulation (Procedural) Rules 2003. The Government of Barbados has granted BLPC a franchise to generate, transmit and distribute electricity on the island until 2028. In 2019, the Government of Barbados passed legislation amending the number of licenses required for the supply of electricity from a single integrated license which currently exists to multiple licenses for Generation, Transmission and Distribution, Storage, Dispatch and Sales. BLPC is currently negotiating the terms of the new licenses under the amended legislation.

 

BLPC is regulated under a cost-of-service model, with rates set to recover prudently incurred costs of providing electricity service to customers and provide an appropriate return to investors. BLPC’s approved regulated return on rate base was 10 per cent for 2020 and 2019.

 

On November 6, 2020, BLPC notified the FTC that it plans to file a general rate review application with the FTC in Q1 2021.

 

BLPC has a fuel pass-through mechanism which provides the opportunity to recover all prudently incurred fuel costs from customers in a timely manner. The approved calculation of the fuel charge is adjusted monthly and reported to the regulator.

 

In December 2018, the Government of Barbados signed the Income Tax Amendment Act into law. This legislation, which was effective January 1, 2019, created a new corporate income tax rate schedule and eliminated certain tax credits. At the date of enactment, BLPC was required to remeasure its deferred income tax liability at the new lower corporate income tax rate, resulting in recognition of an income tax recovery of $9.6 million USD of which $6.9 million USD was deferred as a regulatory liability, all of which was recognized in earnings in Q1 2020.

 

Grand Bahama Power Company Limited

GBPC is regulated by the GBPA. The GBPA has granted GBPC a licensed, regulated and exclusive franchise to produce, transmit and distribute electricity on the island until 2054. There is a fuel pass-through mechanism and tariff review policy with new rates submitted every three years. GBPC’s approved regulated return on rate base was 8.34 per cent for 2020 (2019 – 8.5 per cent). In January 2021, the GBPA approved GBPC’s regulated return on rate base of 8.37 per cent for 2021.

 

In December 2016, the GBPA approved that the all-in rate for electricity (fuel and base rates) would be held at 2016 levels over the five-year period from 2017 through 2021. Any over-recovery of fuel costs during this period will be applied to the Hurricane Matthew regulatory deferral, until such time as the deferral is recovered. Should GBPC recover funds in excess of the Hurricane Matthew regulatory deferral, the excess will be placed in a new storm reserve. If balances remain within the Hurricane Matthew deferral at the end of five years, GBPC will have the opportunity to request recovery from customers in future rates.

 

Dominica Electricity Services Ltd.

Domlec is regulated by the Independent Regulatory Commission, Dominica. On October 7, 2013, the Independent Regulatory Commission, Dominica issued a Transmission, Distribution & Supply License and a Generation License, both of which came into effect on January 1, 2014, for a period of 25 years. Domlec’s approved allowable regulated return on rate base was 15 per cent for 2020 and 2019.

 

Domlec has a fuel pass-through mechanism which provides opportunity to recover substantially all prudently incurred fuel costs in a timely manner.

 

108 EMERA 2020 ANNUAL REPORT


 

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

Gas Utilities and Infrastructure

 

PGS

PGS is regulated by the FPSC. The FPSC sets rates at a level that allows utilities such as PGS to collect total revenues or revenue requirements equal to their cost of providing service, plus an appropriate return on invested capital.

 

PGS’s approved ROE range for 2020 and 2019 was 9.25 per cent to 11.75 per cent, based on an allowed equity capital structure of 54.7 per cent. An ROE of 10.75 per cent was used for the calculation of return on investments for clauses.

 

PGS recovers the costs it pays for gas supply and interstate transportation for system supply through its purchased gas adjustment clause. This clause is designed to recover actual costs incurred by PGS for purchased gas, gas storage services, interstate pipeline capacity, and other related items associated with the purchase, distribution, and sale of natural gas to its customers. These charges may be adjusted monthly based on a cap approved annually by the FPSC.

 

The FPSC annually approves cost-recovery rates for conservation costs and Cast Iron/Bare Steel Pipe Replacement costs, including a return on capital invested incurred in developing and implementing energy conservation programs. The Cast Iron/ Bare Steel Pipe Replacement clause is to recover the cost of accelerating the replacement of cast iron and bare steel distribution lines in the PGS system. The FPSC approved a replacement program of approximately 5 per cent, or 800 kilometres, of the PGS system at a cost of approximately $80 million USD over a 10-year period beginning in 2013. In February 2017, the FPSC approved an amendment to the cast iron bare steel rider to include certain plastic materials and pipe deemed obsolete by Pipeline and Hazardous Materials Safety Administration, totaling approximately 880 kilometres. PGS estimates that all cast iron and bare steel pipe will be removed from its system by 2022, with the replacement of obsolete plastic pipe continuing until 2028 under the rider.

 

PGS was permitted to initiate a general base rate proceeding during 2020, provided the new rates do not become effective before January 1, 2021. On June 8, 2020, PGS filed a petition for an increase in rates and service charges effective January 2021. On November 19, 2020, the FPSC approved a settlement agreement filed by PGS. The settlement agreement allows for an increase to base rates by $58 million USD annually effective January 2021, which is a $34 million USD increase in revenue and $24 million USD increase of revenues previously recovered through the cast iron and bare steel replacement rider. This settlement agreement includes an allowed regulatory ROE range of 8.9 per cent to 11.0 per cent with a 9.9 per cent midpoint. It provides PGS the ability to reverse a total of $34 million USD of accumulated depreciation through 2023 and sets new depreciation rates going into effect January 1, 2021 that are consistent with PGS’s current overall average depreciation rate. Under the agreement base rates are frozen from January 1, 2021 to December 31, 2023, unless its earned ROE were to fall below 8.9 per cent before that time with an allowed equity in the capital structure of 54.7 per cent from investor sources of capital. The settlement agreement provides for the deferral of income taxes as a result of changes in tax laws. The changes would be reflected as a regulatory asset or liability and either result in an increase or a decrease in customer rates through a subsequent regulatory process.

 

NMGC

NMGC is subject to regulation by the NMPRC. The NMPRC sets rates at a level that allows NMGC to collect total revenues equal to its cost of providing service, plus an appropriate return on invested capital.

 

NMGC’s approved ROE for 2020 was 9.10 per cent and for 2019 ranged from 9.10-10.0 per cent. Beginning January 1, 2021, the approved ROE is 9.375 per cent, on an allowed equity capital structure of 52 per cent.

 

NMGC recovers gas supply costs through a purchased gas adjustment clause (“PGAC”). This clause recovers NMGC’s actual costs for purchased gas, gas storage services, interstate pipeline capacity, and other related items associated with the purchase, distribution, and sale of natural gas to its customers. On a monthly basis, NMGC can adjust the charges based on the next month’s expected cost of gas and any prior month under-recovery or over-recovery. The NMPRC requires that NMGC annually file a reconciliation of the PGAC period costs and recoveries. NMGC must file a PGAC Continuation Filing with the NMPRC every four years to establish that the continued use of the PGAC is reasonable and necessary. In December 2020, NMGC received approval of its PGAC Continuation Filing for the four-year period ending December 2024.

 

EMERA 2020 ANNUAL REPORT 109


 

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

NMGC filed a rate case in December 2019. NMGC reached an unopposed stipulated settlement of the case which was approved by the NMPRC in December 2020. The new rates reflect the recovery of capital investment in pipelines and related infrastructure and results in an increase in revenue of approximately $5 million USD annually effective January 2021.The stipulated settlement agreement includes an allowed regulatory ROE 9.375 per cent on an allowed equity capital structure of 52 per cent. Under the agreement base rates are frozen from January 1, 2021 to December 31, 2022, unless new federal tax rates are enacted, in which case NMGC can file for new rates to be effective earlier than January 1, 2023.

 

On July 17, 2019, the NMPRC approved a rate increase for NMGC effective August 2019 and allowed NMGC to retain tax reform benefits realized from January 1, 2018 to the effective date of the new rates. The new rates were phased in over two years, resulting in an annual revenue increase of approximately $3 million USD. The deferred income tax regulatory liability of $11 million ($8 million USD) recorded at December 31, 2018 to reflect deferred tax benefits was recognized in revenue in Q2 2019. The NMPRC also approved the utility’s weather adjustment mechanism. This clause is designed to lower the variability of weather impacts during the heating season period of October through April annually. The Weather Normalization Mechanism will make customer rates and Company revenue more predictable by minimizing the impact of warmer than usual or colder than usual weather. Revenue increases or decreases captured in the weather normalization mechanism from October to April will be adjusted annually in October of the following heating season.

 

Beginning in August 2019, the NMPRC approved a change in the treatment of net operating loss carryforwards. As a result of this change, a tax benefit of approximately $7 million ($5 million USD) was recognized in earnings in Q3 2019.

 

Brunswick Pipeline

Brunswick Pipeline is a 145-kilometre pipeline delivering natural gas from the Canaport™ re-gasified liquefied natural gas (“LNG”) import terminal near Saint John, New Brunswick to markets in the northeastern United States. Brunswick Pipeline entered into a 25-year firm service agreement commencing in July 2009 with Repsol Energy Canada. The agreement provides for a predetermined toll increase in the fifth and fifteenth year of the contract. The pipeline is considered a Group II pipeline regulated by the Canada Energy Regulator (“CER”). The CER Gas Transportation Tariff is filed by Brunswick Pipeline in compliance with the requirements of the CER Act and sets forth the terms and conditions of the transportation rendered by Brunswick Pipeline.

 

8. INVESTMENTS SUBJECT TO SIGNIFICANT INFLUENCE AND EQUITY INCOME

 

millions of Canadian dollars Carrying Value
As at December 31
Equity Income For the
 year ended
December 31

Percentage

of

ownership

2020 2019 2020 2019 2020
LIL (1) $ 629 $ 579 $ 49 $ 45 45.6
NSPML 547 554 47 46 100.0
M&NP (2) 129 138 20 22 12.9
Lucelec (2) 41 41 4 3 19.5
Bear Swamp (3) 29 35 50.0
Other Investments 3
$ 1,346 $ 1,312 $ 149 $ 154
(1) Emera indirectly owns 100 per cent of the Class B units, which comprises 24.9 per cent of the total units issued. Emera’s percentage ownership in LIL is subject to change, based on the balance of capital investments required from Emera and Nalcor Energy to complete construction of the LIL. Emera’s ultimate percentage investment in LIL will be determined upon final costing of all transmission projects related to the Muskrat Falls development, including the LIL, Labrador Transmission Assets and Maritime Link Projects, such that Emera’s total investment in the Maritime Link and LIL will equal 49 per cent of the cost of all of these transmission developments.

(2) Although Emera’s ownership percentage of these entities is relatively low, it is considered to have significant influence over the operating and financial decisions of these companies through Board representation. Therefore, Emera records its investment in these entities using the equity method.

(3) The investment balance in Bear Swamp is in a credit position primarily as a result of a $179 million distribution received in 2015. Bear Swamp’s credit investment balance of $118 million (2019 – $137 million) is recorded in “Other long-term liabilities” on the Consolidated Balance Sheets.

 

Equity investments include a $12 million difference between the cost and the underlying fair value of the investees’ assets as at the date of acquisition. The excess is attributable to goodwill.

 

110 EMERA 2020 ANNUAL REPORT


 

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

Emera accounts for its variable interest investment in NSPML as an equity investment (note 32). NSPML’s consolidated summarized balance sheets are illustrated as follows:

 

As at
millions of Canadian dollars

   

December 31
2020

   

December 31
2019

 
Balance Sheets
Current assets $ 57 $ 69
Property, plant and equipment 1,629 1,671
Regulatory assets 210 177
Non-current assets 32 32
Total assets $ 1,928 $ 1,949
Current liabilities $ 56 $ 23
Long-term debt (1) 1,228 1,288
Non-current liabilities 97 84
Equity 547 554
Total liabilities and equity $ 1,928 $ 1,949
(1) The project debt has been guaranteed by the Government of Canada.

 

9. OTHER INCOME (EXPENSES), NET

 

Other income (expenses), net consisted of the following:

 

For the Year ended December 31
millions of Canadian dollars 2020 2020
Allowance for equity funds used during construction $ 45 $ 21
Gain on sale of Emera Maine, net of transaction costs (1) 585
TECO Guatemala Holdings award (2) 49
Other 29 (9 )
$ 708 $ 12
(1) Refer to note 4 for further detail related to the gain on sale of Emera Maine.

(2) Refer to note 27 for further detail related to the TECO Guatemala Holdings award.

 

10. INCOME TAXES

 

The income tax provision, for the years ended December 31, differs from that computed using the enacted combined Canadian federal and provincial statutory income tax rate for the following reasons:

 

millions of Canadian dollars 2020 2019
Income before provision for income taxes $ 1,325 $ 771
Statutory income tax rate 29.5% 31%
Income taxes, at statutory income tax rate 391 239
Additional impact from the sale of Emera Maine 102
Deferred income taxes on regulated income recorded as regulatory assets and regulatory liabilities (48 ) (66 )
Foreign tax rate variance (45 ) (49 )
Amortization of deferred income tax regulatory liabilities (44 ) (36 )
Tax effect of equity earnings (15 ) (15 )
Other (12 )
Income tax expense $ 341 $ 61
Effective income tax rate 26% 8%

  

The increase in the effective income tax rate was primarily due to the sale of Emera Maine.

 

EMERA 2020 ANNUAL REPORT 111


 

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

On March 10, 2020, Bill 243 of the Nova Scotia Financial Measures (2020) Act (“the Financial Measures Act”) was enacted, which included a reduction in the Nova Scotia provincial corporate income tax rate from 16 per cent to 14 per cent. As a result, the Company’s combined Canadian federal and provincial statutory income tax rate was reduced from 31 per cent to 29.5 per cent for 2020 and further reduced to 29 per cent for subsequent years.

 

As a result of this, the Company, in Q1 2020, was required to revalue certain of its Canadian deferred income tax assets and liabilities based on the new tax rates. The Company recorded a reduction of $52 million to its net deferred income tax liabilities and an offsetting reduction to its net deferred income tax regulatory asset, as the benefit of lower net deferred income tax liabilities is expected to be returned to customers in future years. The Company also recognized a $12 million income tax expense in Q1 2020 as a result of the revaluation of certain net deferred income tax assets.

 

On March 25, 2020, Bill C-13, the Canadian COVID-19 Emergency Response Act (“the COVID-19 Act”) was enacted, guaranteeing rapid implementation and administration of measures to protect Canadians’ health and safety, and stabilize the economy. In addition, the Government of Canada announced the opportunity for businesses to defer certain tax payments. There have been no material impacts to Emera’s financial position from the COVID-19 Act or the Government of Canada’s announcements.

 

On March 27, 2020, the United States Coronavirus Aid, Relief, and Economic Security (CARES) Act (“the CARES Act”) was signed into law. The CARES Act includes several business provisions including deferral of employer payroll taxes, an employee retention payroll tax credit, temporary changes to business interest expense disallowance rules, changes to net operating loss carryback and limitation rules and corporate alternative minimum tax (“AMT”) relief. Under the new AMT provisions, companies can accelerate the refund of AMT credit carryforwards. As a result, in Q1 2020, the Company reclassified $77 million of AMT credit carryforwards from deferred income tax assets to receivables and other current assets. The Company received $145 million of refundable AMT credit carryforwards in Q4 2020. The Company has not had any other material impacts from the CARES Act.

 

The following table reflects the composition of taxes on income from continuing operations presented in the Consolidated Statements of Income for the years ended December 31:

 

millions of Canadian dollars 2020 2019
Current income taxes
Canada $ 18 $ (19 )
United States (58 ) (46 )
Other 1
Deferred income taxes
Canada 20 45
United States 426 137
Other (9 )
Investment tax credits
United States (10 ) (9 )
Operating loss carryforwards
Canada (46 ) (48 )
Income tax expense $ 341 $ 61

 

The following table reflects the composition of income before provision for income taxes presented in the Consolidated Statements of Income for the years ended December 31:

 

millions of Canadian dollars 2020 2019
Canada $ 176 $ 98
United States 1,142 682
Other 7 (9 )
Income before provision for income taxes $ 1,325 $ 771

 

112 EMERA 2020 ANNUAL REPORT


 

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

The deferred income tax assets and liabilities presented in the Consolidated Balance Sheets as at December 31 consisted of the following:

 

millions of Canadian dollars 2020 2019
Deferred income tax assets:
Tax loss carryforwards $ 724 $ 908
Tax credit carryforwards 319 311
Regulatory liabilities – cost of removal 184 195
Derivative instruments 108 145
Other 375 413
Total deferred income tax assets before valuation allowance 1,710 1,972
Valuation allowance (202 ) (193 )
Total deferred income tax assets after valuation allowance $ 1,508 $ 1,779
Deferred income tax (liabilities):
Property, plant and equipment $ (2,450 ) $ (2,382 )
Derivative instruments (93 ) (148 )
Other (385 ) (348 )
Total deferred income tax liabilities (2,928 ) (2,878 )
Consolidated Balance Sheets presentation:
Long-term deferred income tax assets $ 209 $ 186
Long-term deferred income tax liabilities (1,629 ) (1,285 )
Net deferred income tax liabilities $ (1,420 ) $ (1,099 )

 

Considering all evidence regarding the utilization of the Company’s deferred income tax assets, it has been determined that Emera is more likely than not to realize all recorded deferred income tax assets, except for certain loss carryforwards and unrealized capital losses on investments. A valuation allowance of $202 million has been recorded as at December 31, 2020 (2019 – $193 million) related to the loss carryforwards and investments.

 

The Company intends to indefinitely reinvest earnings from certain foreign operations. Accordingly, $2.7 billion as at December 31, 2020 (2019 – $1.9 billion) in cumulative temporary differences for which deferred taxes might otherwise be required, have not been recognized. It is impractical to estimate the amount of income and withholding tax that might be payable if a reversal of temporary differences occurred.

 

Emera’s net operating loss (“NOL”), capital loss and tax credit carryforwards and their expiration periods as at December 31, 2020 consisted of the following:

 

millions of Canadian dollars Gross Tax
Carryforwards
Unrecognized
Amounts
Net Tax
Carryforwards
Expiration
Period
Canada
NOL $ 1,370 $ (619 ) $ 751 2027–2040
Capital loss 61 (61 ) Indefinite
United States
Federal NOL $ 1,412 $ $ 1,412 2030–2040
State NOL 563 563 2032–2040
Tax credit 319 319 2025–2040
Other
NOL $ 39 $ (39 ) $ 2021–2027

 

The following table provides details of the change in unrecognized tax benefits for the years ended December 31 as follows:

 

millions of Canadian dollars 2020 2019
Balance, January 1 $ 29 $ 26
Increases due to tax positions related to current year 1 2
Increases due to tax positions related to a prior year 2 1
Decreases due to tax positions related to a prior year (2 )
Balance, December 31 $ 30 $ 29

 

EMERA 2020 ANNUAL REPORT 113


 

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

The total amount of unrecognized tax benefits as at December 31, 2020 was $30 million (2019 – $29 million), which would affect the effective tax rate if recognized. The total amount of accrued interest with respect to unrecognized tax benefits was $6 million (2019 – $5 million) with $1 million of interest expense recognized in the Consolidated Statements of Income (2019 – $1 million). No penalties have been accrued. The balance of unrecognized tax benefits could change in the next 12 months as a result of resolving Canada Revenue Agency (“CRA”) and Internal Revenue Service audits. A reasonable estimate of any change cannot be made at this time.

 

NSPI and the CRA are currently in a dispute with respect to the timing of certain tax deductions for NSPI’s 2006 through 2010 taxation years. The ultimate permissibility of the tax deductions is not in dispute; rather, it is the timing of those deductions. The cumulative net amount in dispute to date is $62 million, including interest. NSPI has prepaid $23 million of the amount in dispute, as required by CRA.

 

On November 29, 2019, NSPI filed a Notice of Appeal with the Tax Court of Canada with respect to its dispute. Should NSPI be successful in defending its position, all payments including applicable interest will be refunded. If NSPI is unsuccessful in defending any portion of its position, the resulting taxes and applicable interest will be deducted from amounts previously paid, with the excess, if any, owing to CRA. The related tax deductions will be available in subsequent years.

 

Should NSPI be similarly reassessed by the CRA for years not currently in dispute, further payments will be required; however, the ultimate permissibility of these deductions would be similarly not in dispute.

 

NSPI and its advisors believe that NSPI has reported its tax position appropriately. NSPI continues to assess its options to resolving the dispute; however, the outcome of the Appeal process is not determinable at this time.

 

Emera files a Canadian federal income tax return, which includes its Nova Scotia and New Brunswick provincial income tax. Emera’s subsidiaries file Canadian, US, Barbados, St. Lucia and Dominica income tax returns. As at December 31, 2020, the Company’s tax years still open to examination by taxing authorities include 2005 and subsequent years.

 

11. COMMON STOCK

 

Authorized: Unlimited number of non-par value common shares.

 

2020 2019
Issued and outstanding: millions of
shares
millions of
Canadian
dollars
millions of
shares
millions of
Canadian
dollars
Balance, December 31, 2019 242.48 $ 6,216 234.12 $ 5,816
Conversion of Convertible Debentures 0.03 1
Issuance of common stock (1) (2) 4.54 251 1.77 99
Issued under Purchase Plans at market rate 3.99 219 3.99 202
Discount on shares purchased under Dividend Reinvestment Plan (4 ) (7 )
Options exercised under senior management share option plan 0.42 20 2.57 104
Employee Share Purchase Plan 3 1
Balance, December 31, 2020 251.43 $ 6,705 242.48 $ 6,216
(1) As at December 31, 2019, a total of 1,768,120 common shares were issued under Emera’s at-the-market program (“ATM program”) at an average price of $56.56 per share for gross proceeds of $100 million ($99 million net of issuance costs).

(2) For the year ended December 31, 2020, 4,544,025 common shares were issued under Emera’s ATM program at an average price of $56.04 per share for gross proceeds of $255 million ($251 million net of issuance costs).

 

114 EMERA 2020 ANNUAL REPORT


 

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

On July 11, 2019, Emera established an ATM Program that allows the Company to issue up to $600 million of common shares to the public from time to time, at the Company’s discretion, at the prevailing market price. The ATM Program was established under a prospectus supplement to the Company’s short-form base shelf prospectus which expires on July 14, 2021. As at December 31, 2020, an aggregate gross sales limit of $245 million remains available for issuance under the ATM program.

 

On November 17, 2020, Emera filed an amendment to its July 11, 2019 prospectus supplement which established its ATM program. This amendment reflected changes in securities regulations related to ATM programs which were effective August 31, 2020. The amendment includes removal of the daily trading limit which previously provided that the number of shares sold could not exceed 25 per cent of the daily trading volume of the shares.

 

As at December 31, 2020, the following common shares were reserved for issuance: 3.5 million (2019 – 3.9 million) under the senior management stock option plan, 3.5 million (2019 – 0.9 million) under the employee common share purchase plan and 5.1 million (2019 – 8.8 million) under the dividend reinvestment plan (“DRIP”).

 

The issuance of common shares under the common share compensation arrangements does not allow the plans to exceed 10 per cent of Emera’s outstanding common shares. As at December 31, 2020, Emera is in compliance with this requirement.

 

12. EARNINGS PER SHARE

 

Basic earnings per share (“EPS”) is determined by dividing net income attributable to common shareholders by the weighted average number of common shares and DSUs outstanding during the period. Diluted EPS is computed by dividing net income attributable to common shareholders by the weighted average number of common shares and DSUs outstanding during the period, adjusted for the exercise and/or conversion of all potentially dilutive securities. Such dilutive items include Company contributions to the senior management stock option plan, convertible debentures and shares issued under the dividend reinvestment plan.

 

The following table reconciles the computation of basic and diluted earnings per share:

 

For the Year ended December 31
millions of Canadian dollars (except per share amounts) 2020 2019
Numerator
Net income attributable to common shareholders $ 937.6 $ 662.8
Diluted numerator 937.6 662.8
Denominator
Weighted average shares of common stock outstanding 246.5 238.5
Weighted average deferred share units outstanding 1.3 1.4
Weighted average shares of common stock outstanding – basic 247.8 239.9
Stock-based compensation 0.4 0.6
Weighted average shares of common stock outstanding – diluted 248.2 240.5
Earnings per common share
Basic $ 3.78 $ 2.76
Diluted $ 3.78 $ 2.76

 

EMERA 2020 ANNUAL REPORT 115


 

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

13. ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS)

 

The components of accumulated other comprehensive income are as follows:

 

millions of Canadian dollars   Unrealized
(loss) gain on
translation of
self-sustaining
foreign
operations
    Net change in
net investment
hedges
    (Losses) gains
on derivatives
recognized
as cash flow
hedges
    Net change
on available-
for-sale
investments
    Net change in
unrecognized
pension
and post-
retirement
benefit costs
    Total AOCI  
For the year ended December 31, 2020                                    
Balance, January 1, 2020   $ 253     $ 4     $ (1 )   $ (1 )   $ (160 )   $ 95  
Other comprehensive income (loss) before reclassifications     (201 )     26                         (175 )
Amounts reclassified from accumulated other comprehensive income loss (gain)                 2             (1 )     1  
Net current period other comprehensive income (loss)     (201 )     26       2             (1 )     (174 )
Balance, December 31, 2020   $ 52     $ 30     $ 1     $ (1 )   $ (161 )   $ (79 )
                                                 
For the year ended December 31, 2019                                                
Balance, January 1, 2019   $ 654     $ (74 )   $ (7 )   $ (1 )   $ (234 )   $ 338  
Other comprehensive income (loss) before reclassifications     (401 )     78       3                   (320 )
Amounts reclassified from accumulated other comprehensive income loss                 3             74       77  
Net current period other comprehensive income (loss)     (401 )     78       6             74       (243 )
Balance, December 31, 2019   $ 253     $ 4     $ (1 )   $ (1 )   $ (160 )   $ 95  

 

The reclassifications out of accumulated other comprehensive income (loss) are as follows:

 

For the       Year ended December 31  
millions of Canadian dollars       2020     2019  
Affected line item in the Consolidated Financial Statements                
Losses on derivatives recognized as cash flow hedges                
Foreign exchange forwards   Operating revenue – regulated   $ 2     $ 3  
Total before tax         2       3  
Total net of tax       $ 2     $ 3  
Net change in unrecognized pension and post-retirement benefit costs                
Actuarial losses (gains)   Other income, net   $ 15     $ 17  
Past service costs (gains)   Other income, net     (1 )     (1 )
Amounts reclassified into obligations   Pension and post-retirement benefits     (16 )     39  
Amounts reclassified into obligations   Regulatory assets           28  
Total before tax         (2 )     83  
    Income tax recovery (expense)     1       (9 )
Total net of tax       $ (1 )   $ 74  
Total reclassifications out of AOCI, net of tax, for the period   $ 1     $ 77  

 

116 EMERA 2020 ANNUAL REPORT


 

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

14. INVENTORY

 

As at   December 31     December 31  
millions of Canadian dollars   2020     2019  
Fuel   $ 199     $ 232  
Materials     254       235  
    $ 453     $ 467  

 

15. DERIVATIVE INSTRUMENTS

 

Derivative assets and liabilities relating to the foregoing categories consisted of the following:

 

    Derivative Assets     Derivative Liabilities  
As at   December 31     December 31     December 31     December 31  
millions of Canadian dollars   2020     2019     2020     2019  
Cash flow hedges                                
Interest rate hedge   $ 1     $     $     $  
Foreign exchange forwards                       1  
      1                   1  
Regulatory deferral                                
Commodity swaps and forwards                                
Coal purchases     1       8       6       39  
Power purchases     10       23       34       36  
Natural gas purchases and sales     4       2       2       5  
Heavy fuel oil purchases     1       1       5        
Foreign exchange forwards           2       17       6  
      16       36       64       86  
HFT derivatives                                
Power swaps and physical contracts     13       19       13       22  
Natural gas swaps, futures, forwards, physical contracts     139       151       346       381  
      152       170       359       403  
Other derivatives                                
Equity derivatives           1       1        
Foreign exchange forwards     15                    
      15       1       1        
Total gross current derivatives     184       207       424       490  
Impact of master netting agreements with intent to settle net or simultaneously     (86 )     (120 )     (86 )     (120 )
      98       87       338       370  
Current     73       54       251       268  
Long-term     25       33       87       102  
Total derivatives   $ 98     $ 87     $ 338     $ 370  

 

Derivative assets and liabilities are classified as current or long-term based upon the maturities of the underlying contracts.

 

Details of master netting agreements, shown net on the Consolidated Balance Sheets, are summarized in the following table:

 

    Derivative Assets     Derivative Liabilities  
As at   December 31     December 31     December 31     December 31  
millions of Canadian dollars   2020     2019     2020     2019  
Regulatory deferral   $ 2     $ 8     $ 2     $ 8  
HFT derivatives     84       112       84       112  
Total impact of master netting agreements with intent to settle net or simultaneously   $ 86     $ 120     $ 86     $ 120  

 

EMERA 2020 ANNUAL REPORT 117


 

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

CASH FLOW HEDGES

As at December 31, 2020 the Company had a treasury lock in place to hedge the interest rate risk associated with the refinancing of long-term debt due in June 2021. During 2020 the Company also had foreign exchange forwards to hedge the currency risk for revenue streams denominated in foreign currency for Brunswick Pipeline. The foreign exchange forwards designated as cash flow hedges settled in 2020.

 

The amounts related to cash flow hedges recorded in income and AOCI consisted of the following:

 

For the         Year ended December 31  
millions of Canadian dollars         2020     2019  
     

Foreign

exchange

forwards

     

Interest

rate

hedge

     

Foreign

exchange

forwards

 
Realized gain (loss) in operating revenue – regulated   $ (2 )   $     $ (3 )
Total gains (losses) in net income   $ (2 )   $     $ (3 )

 

As at         December 31  
millions of Canadian dollars         2020     2019  
     

Foreign

exchange

forwards

     

Interest

rate

hedge

     

Foreign

exchange

forwards

 
Total unrealized gain (loss) in AOCI – effective portion, net of tax   $     $ 1     $ (1 )

 

The Company expects $1 million of unrealized gains currently in AOCI to be reclassified into net income within the next 12 months, as the underlying hedged transactions settle.

 

As at December 31, 2020, the Company had the following notional volumes of outstanding derivatives designated as cash flow hedges that are expected to settle as outlined below:

 

millions   2021  
U.S. Treasury lock (USD)   $ 350  

 

REGULATORY DEFERRAL

The Company has recorded the following changes in realized and unrealized gains (losses) with respect to derivatives receiving regulatory deferral:

 

For the   Year ended December 31  
millions of Canadian dollars         2020           2019  
     

Commodity

swaps and

forwards

     

Foreign

exchange

forwards

     

Commodity

swaps and

forwards

     

Foreign

exchange

forwards

 
Unrealized gain (loss) in regulatory assets   $ (36 )   $ (11 )   $ (89 )   $ (6 )
Unrealized gain (loss) in regulatory liabilities     3       3       9       (8 )
Realized gain (loss) in regulatory assets     2                    
Realized (gain) loss in regulatory liabilities     14             (2 )      
Realized (gain) loss in inventory (1)     8       (2 )     (36 )     (11 )
Realized (gain) loss in regulated fuel for generation and purchased power (2)     24       (3 )     3       (8 )
Total change derivative instruments   $ 15     $ (13 )   $ (115 )   $ (33 )

(1) Realized (gains) losses will be recognized in fuel for generation and purchased power when the hedged item is consumed.
(2) Realized (gains) losses on derivative instruments settled and consumed in the period and hedging relationships that have been terminated or the hedged transaction is no longer probable.

 

118 EMERA 2020 ANNUAL REPORT


 

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

COMMODITY SWAPS AND FORWARDS

As at December 31, 2020, the Company had the following notional volumes of commodity swaps and forward contracts designated for regulatory deferral that are expected to settle as outlined below:

 

millions   2021     2022–2023  
    Purchases     Purchases  
Natural Gas (Mmbtu)     5       7  
Power (MWh)     2       2  
Heavy fuel oil (bbls)           1  
Coal (metric tonnes)           1  

 

FOREIGN EXCHANGE SWAPS AND FORWARDS

As at December 31, 2020, the Company had the following notional volumes of foreign exchange swaps and forward contracts designated as regulated deferral that are expected to settle as outlined below:

 

    2021     2022–2023  
Foreign exchange contracts (millions of US dollars)   $ 160     $ 135  
Weighted average rate     1.3339       1.3266  
% of USD requirements     78%     37%

 

The Company reassesses foreign exchange forecasted periodically and will enter into additional hedges or unwind existing hedges, as required.

 

HELD-FOR-TRADING DERIVATIVES

In the ordinary course of its business, Emera enters into physical contracts for the purchase and sale of natural gas, as well as power and natural gas swaps, forwards and futures, to economically hedge those physical contracts. These derivatives are all considered HFT.

 

The Company has recognized the following realized and unrealized gains (losses) with respect to HFT derivatives:

 

For the   Year ended December 31  
millions of Canadian dollars   2020     2019  
Power swaps and physical contracts in non-regulated operating revenues   $ (1 )   $ 1  
Natural gas swaps, forwards, futures and physical contracts in non-regulated operating revenues     205       281  
Power swaps, forwards, futures and physical contracts in non-regulated fuel for generation and purchased power     (4 )     (6 )
    $ 200     $ 276  

 

As at December 31, 2020, the Company had the following notional volumes of outstanding HFT derivatives that are expected to settle as outlined below:

 

millions   2021     2022     2023     2024     2025  
Natural gas purchases (Mmbtu)     387       61       45       26       26  
Natural gas sales (Mmbtu)     412       50       17       2       2  
Power purchases (MWh)     2                          
Power sales (MWh)     1                          

 

EMERA 2020 ANNUAL REPORT 119


 

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

OTHER DERIVATIVES

As at December 31, 2020, the Company had equity derivatives in place to manage the cash flow risk associated with forecasted future cash settlements of deferred compensation obligations and foreign exchange forwards in place to manage cash flow risk associated with forecasted US dollar cash inflows. The equity derivative hedges the return on 2.8 million shares and extends until December of 2021. The foreign exchange forwards have a combined notional amount of $100 million USD and expire in 2021.

 

For the               Year ended December 31  
millions of Canadian dollars         2020           2019  
     

Foreign

Exchange

Forwards

     

Equity

Derivatives

     

Foreign

Exchange

Forwards

     

Equity

Derivatives

 
Unrealized gain (loss) in operating, maintenance and general   $     $ (1 )   $     $ 1  
Unrealized gain (loss) in other income (expense), net     15                    
Realized gain (loss) in operating, maintenance and general           (3 )           27  
Realized gain (loss) in other income (expense)     (2 )                  
Total gains (losses) in net income   $ 13     $ (4 )   $     $ 28  

 

CREDIT RISK

The Company is exposed to credit risk with respect to amounts receivable from customers, energy marketing collateral deposits and derivative assets. Credit risk is the potential loss from a counterparty’s non-performance under an agreement. The Company manages credit risk with policies and procedures for counterparty analysis, exposure measurement, and exposure monitoring and mitigation. Credit assessments are conducted on all new customers and counterparties, and deposits or collateral are requested on any high risk accounts.

 

The Company assesses the potential for credit losses on a regular basis, and where appropriate, maintains provisions. With respect to counterparties, the Company has implemented procedures to monitor the creditworthiness and credit exposure of counterparties and to consider default probability in valuing the counterparty positions. The Company monitors counterparties’ credit standing, including those that are experiencing financial problems, have significant swings in default probability rates, have credit rating changes by external rating agencies, or have changes in ownership. Net liability positions are adjusted based on the Company’s current default probability. Net asset positions are adjusted based on the counterparty’s current default probability. The Company assesses credit risk internally for counterparties that are not rated.

 

As at December 31, 2020, the maximum exposure the Company has to credit risk is $805 million (2019 – $860 million), which includes accounts receivable net of collateral/deposits and assets related to derivatives.

 

It is possible that volatility in commodity prices could cause the Company to have material credit risk exposures with one or more counterparties. If such counterparties fail to perform their obligations under one or more agreements, the Company could suffer a material financial loss. The Company transacts with counterparties as part of its risk management strategy for managing commodity price, foreign exchange and interest rate risk. Counterparties that exceed established credit limits can provide a cash deposit or letter of credit to the Company for the value in excess of the credit limit where contractually required. The total cash deposits/collateral on hand as at December 31, 2020 was $251 million (2019 – $259 million), which mitigates the Company’s maximum credit risk exposure. The Company uses the cash as payment for the amount receivable or returns the deposit/ collateral to the customer/counterparty where it is no longer required by the Company.

 

The Company enters into commodity master arrangements with its counterparties to manage certain risks, including credit risk to these counterparties. The Company generally enters into International Swaps and Derivatives Association agreements (“ISDA”), North American Energy Standards Board agreements (“NAESB”) and, or Edison Electric Institute agreements.

The Company believes that entering into such agreements offers protection by creating contractual rights relating to creditworthiness, collateral, non-performance and default.

 

As at December 31, 2020, the Company had $123 million (2019 – $115 million) in financial assets, considered to be past due, which have been outstanding for an average 70 days. The fair value of these financial assets is $101 million (2019 – $106 million), the difference of which is included in the allowance for credit losses. These assets primarily relate to accounts receivable from electric and gas revenue.

 

120 EMERA 2020 ANNUAL REPORT


 

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

CONCENTRATION RISK

The Company’s concentrations of risk consisted of the following:

 

As at   December 31, 2020     December 31, 2019  
   

millions of

Canadian

dollars

   

% of total

exposure

   

millions of

Canadian

dollars

   

% of total

exposure

 
Receivables, net                                
Regulated utilities                                
Residential   $ 341       32 %   $ 344       31 %
Commercial     143       14 %     170       15 %
Industrial     49       5 %     66       6 %
Other     96       9 %     131       12 %
      629       60 %     711       64 %
Trading group                                
Credit rating of A- or above     54       5 %     38       3 %
Credit rating of BBB- to BBB+     41       4 %     59       5 %
Not rated     75       7 %     95       9 %
      170       16 %     192       17 %
Other accounts receivable     159       15 %     184       16 %
Classification as assets held for sale (1)           0 %     (55 )     -5 %
      958       91 %     1,032       92 %
Derivative Instruments (current and long-term)                                
Credit rating of A- or above     60       6 %     47       4 %
Credit rating of BBB- to BBB+     13       1 %     8       1 %
Not rated     25       2 %     32       3 %
      98       9 %     87       8 %
    $ 1,056       100 %   $ 1,119       100 %

(1) Emera Maine’s assets and liabilities were classified as held for sale at December 31, 2019. On March 24, 2020, Emera completed the sale of Emera Maine. Refer to note 4 for further detail.

 

CASH COLLATERAL

The Company’s cash collateral positions consisted of the following:

 

As at   December 31     December 31  
millions of Canadian dollars   2020     2019  
Cash collateral provided to others   $ 69     $ 101  
Cash collateral received from others     6       2  

 

Collateral is posted in the normal course of business based on the Company’s creditworthiness, including its senior unsecured credit rating as determined by certain major credit rating agencies. Certain derivatives contain financial assurance provisions that require collateral to be posted if a material adverse credit-related event occurs. If a material adverse event resulted in the senior unsecured debt falling below investment grade, the counterparties to such derivatives could request ongoing full collateralization.

 

As at December 31, 2020, the total fair value of derivatives in a liability position, was $338 million (December 31, 2019 – $370 million). If the credit ratings of the Company were reduced below investment grade, the full value of the net liability position could be required to be posted as collateral for these derivatives.

 

EMERA 2020 ANNUAL REPORT 121


 

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

16. FAIR VALUE MEASUREMENTS

 

The Company is required to determine the fair value of all derivatives except those which qualify for the NPNS exemption (see note 1) and uses a market approach to do so. The three levels of the fair value hierarchy are defined as follows:

 

Level 1 – Where possible, the Company bases the fair valuation of its financial assets and liabilities on quoted prices in active markets (“quoted prices”) for identical assets and liabilities.

 

Level 2 – Where quoted prices for identical assets and liabilities are not available, the valuation of certain contracts must be based on quoted prices for similar assets and liabilities with an adjustment related to location differences. Also, certain derivatives are valued using quotes from over-the-counter clearing houses.

 

Level 3 – Where the information required for a Level 1 or Level 2 valuation is not available, derivatives must be valued using unobservable or internally-developed inputs. The primary reasons for a Level 3 classification are as follows:

 

While valuations were based on quoted prices, significant assumptions were necessary to reflect seasonal or monthly shaping and locational basis differentials.
The term of certain transactions extends beyond the period when quoted prices are available, and accordingly, assumptions were made to extrapolate prices from the last quoted period through the end of the transaction term.
The valuations of certain transactions were based on internal models, although quoted prices were utilized in the valuations.

 

Derivative assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement.

 

122 EMERA 2020 ANNUAL REPORT


 

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

The following tables set out the classification of the methodology used by the Company to fair value its derivatives:

 

As at           December 31, 2020  
millions of Canadian dollars   Level 1     Level 2     Level 3     Total  
Assets                
Cash flow hedges                                
Interest rate hedge   $ 1     $     $     $ 1  
      1                   1  
Regulatory deferral                                
Commodity swaps and forwards                                
Power purchases     9                   9  
Natural gas purchases and sales     2       1             3  
Heavy fuel oil purchases           2             2  
      11       3             14  
HFT derivatives                                
Power swaps and physical contracts     3       2       2       7  
Natural gas swaps, futures, forwards, physical contracts and related transportation     1       48       12       61  
      4       50       14       68  
Other derivatives                                
Foreign exchange forwards           15             15  
            15             15  
Total assets     16       68       14       98  
Liabilities                                
Regulatory deferral                                
Commodity swaps and forwards                                
Coal purchases           4             4  
Power purchases     33                   33  
Heavy fuel oil purchases     3       3             6  
Natural gas purchases and sales           2             2  
Foreign exchange forwards           17             17  
      36       26             62  
HFT derivatives                                
Power swaps and physical contracts     4       2       1       7  
Natural gas swaps, futures, forwards and physical contracts     1       10       257       268  
      5       12       258       275  
Other derivatives                                
Equity derivatives     1                   1  
      1                   1  
Total liabilities     42       38       258       338  
Net assets (liabilities)   $ (26 )   $ 30     $ (244 )   $ (240 )

 

EMERA 2020 ANNUAL REPORT 123


 

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

As at           December 31, 2019  
millions of Canadian dollars   Level 1     Level 2     Level 3     Total  
Assets                
Regulatory deferral                                
Commodity swaps and forwards                                
Power purchases   $ 23     $     $     $ 23  
Natural gas purchases and sales           2             2  
Heavy fuel oil purchases           1             1  
Foreign exchange forwards           2             2  
      23       5             28  
HFT derivatives                                
Power swaps and physical contracts     1       3       1       5  
Natural gas swaps, futures, forwards, physical contracts and related transportation     (7 )     46       14       53  
      (6 )     49       15       58  
Other derivatives                                
Equity derivatives     1                   1  
      1                   1  
Total assets     18       54       15       87  
Liabilities                                
Cash flow hedges                                
Foreign exchange forwards           1             1  
            1             1  
Regulatory deferral                                
Commodity swaps and forwards                                
Coal purchases           31             31  
Power purchases     36                   36  
Natural gas purchases and sales     3       2             5  
Foreign exchange forwards           6             6  
      39       39             78  
HFT derivatives                                
Power swaps and physical contracts     5       2             7  
Natural gas swaps, futures, forwards and physical contracts     2       33       249       284  
      7       35       249       291  
Total liabilities     46       75       249       370  
Net assets (liabilities)   $ (28 )   $ (21 )   $ (234 )   $ (283 )

 

The change in the fair value of the Level 3 financial assets for the year ended December 31, 2020 was as follows:

 

              HFT Derivatives  
millions of Canadian dollars     Power       Natural gas       Total  
Balance, January 1, 2020   $ 1     $ 14     $ 15  
Total realized and unrealized gains (losses) included in non-regulated operating revenues     3       (2 )     1  
Net transfers out of Level 3     (2 )           (2 )
Balance, December 31, 2020   $ 2     $ 12     $ 14  

 

124 EMERA 2020 ANNUAL REPORT


 

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

The change in the fair value of the Level 3 financial liabilities for the year ended December 31, 2020 was as follows:

 

              HFT Derivatives  
millions of Canadian dollars     Power       Natural gas       Total  
Balance, January 1, 2020   $     $ 249     $ 249  
Total realized and unrealized gains included in non-regulated operating revenues     2       8       10  
Net transfers out of Level 3     (1 )           (1 )
Balance, December 31, 2020   $ 1     $ 257     $ 258  

 

The Company evaluates observable inputs of market data on a quarterly basis to determine if transfers between levels is appropriate. For the year ended December 31, 2020, transfers out of Level 3 were a result of an increase in observable inputs.

 

Significant unobservable inputs used in the fair value measurement of Emera’s natural gas and power derivatives include third-party sourced pricing for instruments based on illiquid markets; internally developed correlation factors and basis differentials; own credit risk; and discount rates. Internally developed correlations and basis differentials are reviewed on a quarterly basis based on statistical analysis of the spot markets in the various illiquid term markets. Discount rates may include a risk premium for those long-term forward contracts with illiquid future price points to incorporate the inherent uncertainty of these points. Any risk premiums for long-term contracts are evaluated by observing similar industry practices and in discussion with industry peers. Significant increases (decreases) in any of these inputs in isolation would result in a significantly lower (higher) fair value measurement.

 

EMERA 2020 ANNUAL REPORT 125


 

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

The following table outlines quantitative information about the significant unobservable inputs used in the fair value measurements categorized within Level 3 of the fair value hierarchy:

 

As at               December 31, 2020  
    Fair     Valuation           Weighted  
millions of Canadian dollars   Value     Technique   Unobservable Input   Range     Average  (1)
Assets                    
HFT derivatives –   $ 1     Modelled pricing   Third-party pricing     $20.50 – $62.45       $31.14  
Power swaps and               Probability of default     0.02% – 9.74%       2.52%
physical contracts               Discount rate     0.01% – 0.73%       0.25%
      1     Modelled pricing   Third-party pricing     $25.70 – $36.05       $29.53  
                Probability of default     0.36% – 0.85%       0.60%
                Discount rate     0.06% – 0.41%       0.28%
                Correlation factor     100% – 100%       100%
HFT derivatives –     18     Modelled pricing   Third-party pricing     $1.66 – $6.22       $2.52  
Natural gas swaps, futures,               Probability of default     0.02% – 2.52%       0.40%
forwards, physical contracts               Discount rate     0.00% – 10.36%       0.75%
      (6 )   Modelled pricing   Third-party pricing     $1.82 – $8.44       $4.66  
                Basis adjustment     $0.00 – $1.33       $0.44  
                Probability of default     0.02% – 12.58%       $1.95  
                Discount rate     0.00% – 0.67%       0.13%
Total assets   $ 14                          
Liabilities                                
HFT derivatives –   $ 1     Modelled pricing   Third-party pricing     $1.13 – $62.45       $36.90  
Power swaps and               Own credit risk     0.02% – 6.85%       2.02%
physical contracts               Discount rate     0.01% – 0.73%       0.34%
      1     Modelled pricing   Third-party pricing     $37.25 – $62.45       $55.00  
                Own credit risk     0.36% – 1.28%       0.83%
                Discount rate     0.01% – 0.40%       0.31%
                Correlation factor     100% – 100%       100%
HFT derivatives –     226     Modelled pricing   Third-party pricing     $1.44 – $6.57       $3.68  
Natural gas swaps, futures,               Own credit risk     0.02% – 2.52%       0.10%
forwards, physical contracts               Discount rate     0.00% – 8.79%       0.43%
      30     Modelled pricing   Third-party pricing     $1.54 – $8.44       $4.69  
                Basis adjustment     $0.00 – $1.33       $0.87  
                Own credit risk     0.03% – 12.58%       0.10%
                Discount rate     0.00% – 0.67%       0.16%
Total liabilities   $ 258                          
Net assets (liabilities)   $ (244 )                        

(1) Unobservable inputs were weighted by the relative fair value of the instruments.

 

126 EMERA 2020 ANNUAL REPORT


 

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

As at               December 31, 2019  
    Fair     Valuation           Weighted  
millions of Canadian dollars   Value     Technique   Unobservable Input   Range     Average  
Assets                      
HFT derivatives –   $ 1     Modelled pricing   Third-party pricing     $21.40 – $74.05       $35.03  
Power swaps and               Probability of default     0.01% – 1.14%       0.21%
physical contracts               Discount rate     0.15% – 6.65%       2.78%
HFT derivatives –     9     Modelled pricing   Third-party pricing     $1.63 – $7.45       $2.37  
Natural gas swaps, futures,               Probability of default     0.01% – 2.31%       0.09%
forwards, physical contracts               Discount rate     0.01% – 20.93%       1.55%
      5     Modelled pricing   Third-party pricing     $1.33 – $8.76       $5.05  
                Basis adjustment     $0.00 – $1.31       $0.76  
                Probability of default     0.01% – 3.33%       0.28%
                Discount rate     0.01% – 4.71%       0.91%
Total assets   $ 15                          
Liabilities                                
HFT derivatives –   $ 228     Modelled pricing   Third-party pricing     $1.54 – $7.45       $4.07  
Natural gas swaps, futures,               Own credit risk     0.01% – 2.31%       0.12%
forwards and physical contracts               Discount rate     0.01% – 18.63%       1.89%
      21     Modelled pricing   Third-party pricing     $1.36 – $9.75       $5.45  
                Basis adjustment     $0.00 – $1.31       $0.91  
                Own credit risk     0.01% – 3.33%       0.06%
                Discount rate     0.01% – 3.76%       0.81%
Total liabilities   $ 249                          
Net assets (liabilities)   $ (234 )                        

 

Long-term debt is a financial liability not measured at fair value on the Consolidated Balance Sheets. The balance consisted of the following:

 

As at                        
    Carrying                      
millions of Canadian dollars   Amount     Fair Value     Level 1     Level 2     Level 3     Total  
December 31, 2020   $ 13,721     $ 16,487     $     $ 16,020     $ 467     $ 16,487  
December 31, 2019   $ 14,180     $ 16,049     $     $ 15,598     $ 451     $ 16,049  

 

The Company has designated $1.2 billion United States dollar denominated Hybrid Notes as a hedge of the foreign currency exposure of its net investment in United States dollar denominated operations. An after-tax foreign currency gain of $26 million was recorded in Other Comprehensive Income for the year ended December 31, 2020 (2019 – $78 million).

 

EMERA 2020 ANNUAL REPORT 127


 

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

17. RELATED PARTY TRANSACTIONS

 

In the ordinary course of business, Emera provides energy, construction and other services and enters into transactions with its subsidiaries, associates and other related companies on terms similar to those offered to non-related parties. Intercompany balances and intercompany transactions have been eliminated on consolidation, except for the net profit on certain transactions between non-regulated and regulated entities in accordance with accounting standards for rate-regulated entities. All material amounts are under normal interest and credit terms.

 

Significant transactions between Emera and its associated companies are as follows:

 

Transactions between NSPI and NSPML related to the Maritime Link assessment are reported in the Consolidated Statements of Income. NSPI’s expense is reported in Regulated fuel for generation and purchased power, totalling $139 million for the year ended December 31, 2020 (2019 – $107 million). NSPML is accounted for as an equity investment and therefore, the corresponding earnings related to this revenue are reflected in Income from equity investments.

Natural gas transportation capacity purchases from M&NP are reported in the Consolidated Statements of Income. Purchases from M&NP reported net in Operating revenues, Non-regulated, totalled $18 million for the year ended December 31, 2020 (2019 – $63 million).

 

There were no significant receivables or payables between Emera and its associated companies reported on Emera’s Consolidated Balance Sheets as at December 31, 2020 and at December 31, 2019.

 

18. RECEIVABLES AND OTHER CURRENT ASSETS

 

Receivables and other current assets consisted of the following:

 

As at   December 31     December 31  
millions of Canadian dollars   2020     2019  
Customer accounts receivable – billed   $ 570     $ 603  
Customer accounts receivable – unbilled     286       265  
Allowance for credit losses     (22 )     (9 )
Capitalized transportation capacity (1)     200       272  
Income tax receivable     11       118  
Prepaid expenses     50       48  
Other     138       189  
    $ 1,233     $ 1,486  
(1) Capitalized transportation capacity represents the value of transportation/storage received by EES on asset management agreements at the inception of the contracts. The asset is amortized over the term of each contract.

 

128 EMERA 2020 ANNUAL REPORT


 

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

19. LEASES

 

LESSEE

 

The Company has operating leases for buildings, land, telecommunication services, and rail cars. Emera’s leases have remaining lease terms of 1 year to 65 years, some of which include options to extend the leases for up to 65 years. These options are included as part of the lease term when it is considered reasonably certain that they will be exercised.

 

As at       December 31     December 31  
millions of Canadian dollars   Classification   2020     2019  
Right-of-use asset   Other long-term assets   $ 61     $ 64  
Lease liabilities                    
Current   Other current liabilities     3       5  
Long-term   Other long-term liabilities     60       61  
Total lease liabilities       $ 63     $ 66  

 

The Company has recorded lease expense of $160 million for the year ended December 31, 2020 (2019 – $172 million), of which $149 million (2019 – $156 million) relates to variable costs for power generation facility finance leases, recorded in “Regulated fuel for generation and purchased power” in the Consolidated Statements of Income.

 

Future minimum lease payments under non-cancellable operating leases for each of the next five years and in aggregate thereafter are as follows:

 

millions of Canadian dollars   2021     2022     2023     2024     2025     Thereafter     Total  
Minimum lease payments   $ 6     $ 6     $ 6     $ 5     $ 4     $ 112     $ 139  
Less imputed interest                                         (76 )
Total   $ 6     $ 6     $ 6     $ 5     $ 4     $ 112     $ 63  

 

Additional information related to Emera’s leases is as follows:

 

    Year ended December 31  
For the   2020     2019  
Cash paid for amounts included in the measurement of lease liabilities:            
Operating cash flows for operating leases (millions of Canadian dollars)   $ 7     $ 7  
Right-of-use assets obtained in exchange for lease obligations:                
Operating leases (millions of Canadian dollars)   $ 7     $ 16  
Weighted average remaining lease term (years)     43       39  
Weighted average discount rate – operating leases     3.96%     4.07%

 

LESSOR

The Company’s net investment in direct finance and sales-type leases primarily relates to Brunswick Pipeline, compressed natural gas (“CNG”) stations and heat pumps.

 

Direct finance and sales-type lease unearned income is recognized in income over the life of the lease using a constant rate of interest equal to the internal rate of return on the lease and is recorded as “Operating revenues – regulated gas” and “Other income (expense), net” on the Consolidated Statements of Income.

 

The Company manages its risk associated with the residual value of the Brunswick Pipeline lease through proper routine maintenance of the asset.

 

Customers have the option to purchase CNG station assets at any time after 2021 by paying a make-whole payment at the date of the purchase based on a targeted internal rate of return or may take possession of the CNG station asset at the end of the lease term for no cost. Customers have the option to purchase heat pumps at the end of the lease term for a nominal fee.

 

EMERA 2020 ANNUAL REPORT 129


 

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

Net investment in direct finance and sales-type leases consist of the following:

 

As at   December 31     December 31  
millions of Canadian dollars   2020     2019  
Total minimum lease payment to be received   $ 1,018     $ 1,066  
Less: amounts representing estimated executory costs     (179 )     (189 )
Minimum lease payments receivable   $ 839     $ 877  
Estimated residual value of leased property (unguaranteed)     183       183  
Less: unearned finance lease income     (487 )     (532 )
Net investment in direct finance and sales-type leases   $ 535     $ 528  
Principal due within one year (included in “Receivables and other current assets”)     18       17  
Net investment in sales-type leases – long-term (included in “Other long-term assets”)     42       38  
Net Investment in direct finance leases – long-term   $ 475     $ 473  

 

As at December 31, 2020, future minimum lease payments to be received for each of the next five years and in aggregate thereafter are as follows:

 

millions of Canadian dollars   2021     2022     2023     2024     2025     Thereafter     Total  
Minimum lease payments to be received   $ 78     $ 77     $ 76     $ 77     $ 79     $ 631     $ 1,018  
Less: executory costs                                                     (179 )
Minimum lease payments receivable   $ 78     $ 77     $ 76     $ 77     $ 79     $ 631     $ 839  

 

20. PROPERTY, PLANT AND EQUIPMENT

 

Property, plant and equipment consisted of the following regulated and non-regulated assets:

 

As at       December 31     December 31  
millions of Canadian dollars   Estimated useful life   2020     2019  
Generation   3 to 131   $ 11,474     $ 11,181  
Transmission   11 to 80     2,414       2,318  
Distribution   4 to 80     5,997       5,820  
Gas transmission and distribution   7 to 85     3,879       3,568  
General plant and other (1)   2 to 60     2,127       2,006  
Total cost         25,891       24,893  
Less: Accumulated depreciation (1)         (8,714 )     (8,317 )
          17,177       16,576  
Construction work in progress (1)         2,358       1,591  
Net book value       $ 19,535     $ 18,167  
(1) SeaCoast owns a 50% undivided ownership interest in a jointly owned 26-mile pipeline lateral located in Florida, which went into service in 2020. At December 31, 2020, SeaCoast’s share of plant in service was $34 million, accumulated depreciation of nil and construction work in progress of nil. At December 31, 2019, SeaCoast’s share of construction work in progress was $8 million. SeaCoast’s undivided ownership interest is financed with its funds and all operations are accounted for as if such participating interest was a wholly owned facility. SeaCoast’s share of direct expenses of the jointly owned pipeline is included in OM&G in the Consolidated Statements of Income.

 

130 EMERA 2020 ANNUAL REPORT


 

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

21. EMPLOYEE BENEFIT PLANS

 

Emera maintains a number of contributory defined-benefit and defined-contribution pension plans, which cover substantially all of its employees. In addition, the Company provides non-pension benefits for its retirees. These plans cover employees in Nova Scotia, New Brunswick, Newfoundland and Labrador, Florida, New Mexico, Barbados, Dominica and Grand Bahama Island. On March 24, 2020, Emera sold Emera Maine, refer to note 4 for further detail. As at December 31, 2019, Emera Maine’s assets and liabilities, including balances related to benefit plans, were classified as held for sale.

 

Emera’s net periodic benefit cost included the following:

 

BENEFIT OBLIGATION AND PLAN ASSETS

The changes in benefit obligation and plan assets, and the funded status for all plans were as follows:

 

For the   Year ended December 31  
millions of Canadian dollars   2020     2019  
Change in Projected Benefit Obligation (“PBO”) and
Accumulated Post-retirement Benefit Obligation (“APBO”)
  Defined benefit
pension plans
    Non-pension
benefit plans
    Defined benefit
pension plans
    Non-pension
benefit plans
 
Balance, January 1   $ 2,822     $ 353     $ 2,650     $ 350  
Service cost     46       5       47       4  
Plan participant contributions     7       5       8       5  
Interest cost     84       10       102       14  
Benefits paid     (135 )     (27 )     (130 )     (23 )
Actuarial losses     189       52       231       19  
Settlements and curtailments     (229 )     (52 )     (20 )      
Foreign currency translation adjustment     (25 )     (7 )     (66 )     (16 )
Balance, December 31     2,759       339       2,822       353  
Change in plan assets                                
Balance, January 1     2,593       56       2,300       49  
Employer contributions     41       21       52       19  
Plan participant contributions     7       5       8       5  
Benefits paid     (135 )     (27 )     (130 )     (23 )
Actual return on assets, net of expenses     310       5       424       7  
Settlements and curtailments     (191 )     (7 )     (7 )      
Foreign currency translation adjustment     (20 )     (1 )     (54 )     (1 )
Balance, December 31     2,605       52       2,593       56  
Funded status, end of year   $ (154 )   $ (287 )   $ (229 )   $ (297 )

 

The actuarial losses recognized in the period are primarily due to losses associated with changes in the discount rate and losses related to changes in member experience, such as terminations, retirements, and deaths. This was partially offset by gains associated with strong asset performance and changes in inflation and compensation-related assumptions.

 

PLANS WITH PBO/APBO IN EXCESS OF PLAN ASSETS

The aggregate financial position for all pension plans where the PBO or APBO (for post-retirement benefit plans) exceeds the plan assets for the years ended December 31 is as follows:

 

millions of Canadian dollars   2020     2019  
    Defined benefit
pension plans
    Non-pension
benefit plans
    Defined benefit
pension plans
    Non-pension
benefit plans
 
PBO/APBO   $ 2,736     $ 308     $ 2,797     $ 323  
Fair value of plan assets     2,568             2,557       7  
Funded status   $ (168 )   $ (308 )   $ (240 )   $ (316 )

 

EMERA 2020 ANNUAL REPORT 131


 

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

PLANS WITH ACCUMULATED BENEFIT OBLIGATION (“ABO”) IN EXCESS OF PLAN ASSETS

The ABO for the defined benefit pension plans was $2,639 million as at December 31, 2020 (2019 – $2,687 million). The aggregate financial position for those plans with an ABO in excess of the plan assets for the years ended December 31 is as follows:

 

millions of Canadian dollars   2020     2019  
    Defined benefit
pension plans
    Defined benefit
pension plans
 
ABO   $ 1,519     $ 2,665  
Fair value of plan assets     1,419       2,557  
Funded status   $ (100 )   $ (108 )

 

BALANCE SHEET

The amounts recognized in the Consolidated Balance Sheets consisted of the following:

 

As at
millions of Canadian dollars
  December 31
2020
    December 31
2019
 
    Defined benefit
pension plans
    Non-pension
benefit plans
    Defined benefit
pension plans
    Non-pension
benefit plans
 
Other current liabilities   $ (4 )   $ (19 )   $ (4 )   $ (18 )
Long-term liabilities     (163 )     (290 )     (206 )     (254 )
Long-term liabilities associated with assets held for sale (1)                 (30 )     (44 )
Other long-term assets     13       20       11       19  
Amount included in deferred income tax     (4 )     (1 )     (7 )     1  
AOCI and regulatory assets, net of tax     443       107       524       72  
Net amount recognized   $ 285     $ (183 )   $ 288     $ (224 )

(1) On March 24, 2020, Emera sold Emera Maine, refer to note 4 for further details. As at December 31, 2019, Emera Maine’s assets and liabilities were classified as held for sale.

 

AMOUNTS RECOGNIZED IN AOCI AND REGULATORY ASSETS

Unamortized gains and losses and past service costs arising on post-retirement benefits are recorded in AOCI or regulatory assets. The following table summarizes the change in AOCI and regulatory assets:

 

millions of Canadian dollars   Regulatory
assets
    Actuarial
(gains) losses
    Past service
(gains) costs
 
Defined Benefit Pension Plans                  
Balance, January 1, 2020   $ 358     $ 160     $ (1 )
Amortized in current period     (25 )     (15 )     1  
Current year addition to AOCI or regulatory assets     (12 )     14        
Change in current year related to sale of Emera Maine     (39 )            
Change in foreign exchange rate     (3 )     1        
Balance, December 31, 2020   $ 279     $ 160     $  
Non-pension benefits plans                        
Balance, January 1, 2020   $ 78     $ (5 )   $  
Amortized in current period                  
Current year addition to AOCI or regulatory assets     48       2        
Change in current year related to sale of Emera Maine     (13 )            
Change in foreign exchange rate     (3 )     (1 )      
Balance, December 31, 2020   $ 110     $ (4 )   $  

 

132 EMERA 2020 ANNUAL REPORT


 

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

    2020     2019  
    Defined benefit
pension plans
    Non-pension
benefit plans
    Defined benefit
pension plans
    Non-pension
benefit plans
 
Actuarial losses (gains)   $ 160     $ (4 )   $ 160     $ (5 )
Past service (gains) costs                 (1 )      
Regulatory assets     279       110       358       78  
Total AOCI and regulatory assets before deferred income taxes     439       106       517       73  
Amount included in deferred income tax assets     4       1       7       (1 )
Net amount in AOCI and regulatory assets   $ 443     $ 107     $ 524     $ 72  

 

BENEFIT COST COMPONENTS

Emera’s net periodic benefit cost included the following:

 

As at   Year ended December 31  
millions of Canadian dollars   2020     2019  
    Defined benefit
pension plans
    Non-pension
benefit plans
    Defined benefit
pension plans
    Non-pension
benefit plans
 
Service cost   $ 46     $ 5     $ 47     $ 4  
Interest cost     84       10       102       14  
Expected return on plan assets     (141 )     (1 )     (147 )     (2 )
Current year amortization of:                                
Actuarial losses (gains)     15             16        
Past service costs (gains)     (1 )           (1 )      
Regulatory assets (liability)     25             20       (5 )
Settlement, curtailments                 1        
Total   $ 28     $ 14     $ 38     $ 11  

 

The expected return on plan assets is determined based on the market-related value of plan assets of $2,476 million as at January 1, 2020 (2019 – $2,401 million), adjusted for interest on certain cash flows during the year. The market-related value of assets is based on a five-year smoothed asset value. Any investment gains (or losses) in excess of (or less than) the expected return on plan assets are recognized on a straight-line basis into the market-related value of assets over a five-year period.

 

PENSION PLAN ASSET ALLOCATIONS

Emera’s investment policy includes discussion regarding the investment philosophy, the level of risk which the Company is prepared to accept with respect to the investment of the Pension Funds, and the basis for measuring the performance of the assets. Central to the policy is the target asset allocation by major asset categories. The objective of the target asset allocation is to diversify risk and to achieve asset returns that meet or exceed the plan’s actuarial assumptions. The diversification of assets reduces the inherent risk in financial markets by requiring that assets be spread out amongst various asset classes. Within each asset class, a further diversification is undertaken through the investment in a broad range of investment and non-investment grade securities. Emera’s target asset allocation is as follows:

 

Canadian Pension Plans

 

Asset class Target Range at Market
Short-term securities 0% to 5%
Fixed income 35% to 50%
Equities:  
Canadian 12% to 22%
Non-Canadian 30% to 55%

 

EMERA 2020 ANNUAL REPORT 133


 

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

Non-Canadian Pension Plans

 

  Target Range at Market
Asset class Weighted Average
Fixed income 30% to 50%
Equities 50% to 70%

 

Pension Plan assets are overseen by the respective Management Pension Committees in the sponsoring companies. All pension investments are in accordance with policies approved by the respective Board of Directors of each sponsoring company.

 

The following tables set out the classification of the methodology used by the Company to fair value its investments:

 

millions of Canadian dollars   December 31, 2020  
    NAV     Level 1     Level 2     Total     Percentage  
Cash and cash equivalents   $     $ 68     $     $ 68       3 %
Net in-transits           (99 )           (99 )     (4 )%
Equity securities:                                        
Canadian equity           154             154       6 %
US equity           380             380       15 %
Other equity           243             243       9 %
Fixed income securities:                                        
Government                 119       119       5 %
Corporate                 141       141       5 %
Other           10       3       13       - %
Mutual funds           88             88       3 %
Other           (3 )     (4 )     (7 )     - %
Open-ended investments measured at NAV (1)     801                   801       31 %
Common collective trusts measured at NAV (2)     704                   704       27 %
Total   $ 1,505     $ 841     $ 259     $ 2,605       100 %

 

millions of Canadian dollars   December 31, 2019  
    NAV     Level 1     Level 2     Total     Percentage  
Cash and cash equivalents   $     $ 44     $     $ 44       2 %
Net in-transits           (48 )           (48 )     (2 )%
Equity securities:                                        
Canadian equity           210             210       8 %
US equity           388             388       15 %
Other equity           176             176       7 %
Fixed income securities:                                        
Government                 93       93       3 %
Corporate                 126       126       5 %
Other           5       9       14       %
Mutual funds           199             199       8 %
Other           (5 )     1       (4 )     %
Open-ended investments measured at NAV (1)     860                   860       33 %
Common collective trusts measured at NAV (2)     535                   535       21 %
Total   $ 1,395     $ 969     $ 229     $ 2,593       100 %

(1) NAV investments are open-ended registered and non-registered mutual funds, collective investment trusts, or pooled funds. NAV’s are calculated daily and the funds honor subscription and redemption activity regularly.

(2) The common collective trusts are private funds valued at NAV. The NAVs are calculated based on bid prices of the underlying securities. Since the prices are not published to external sources, NAV is used as a practical expedient. Certain funds invest primarily in equity securities of domestic and foreign issuers while others invest in long duration U.S. investment grade fixed income assets and seeks to increase return through active management of interest rate and credit risks. The funds honor subscription and redemption activity regularly.

 

Refer to note 16 for more information on the fair value hierarchy and inputs used to measure fair value.

 

134 EMERA 2020 ANNUAL REPORT


 

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

POST-RETIREMENT BENEFIT PLANS

There are no assets set aside to pay for most of the Company’s post-retirement benefit plans. As is common practice, post-retirement health benefits are paid from general accounts as required. The primary exceptions to this is the NMGC Retiree Medical Plan, which is fully funded. Prior to its sale on March 24, 2020, the Emera Maine post-retirement benefit plans were partially funded.

 

INVESTMENTS IN EMERA

As at December 31, 2020 and 2019, the assets related to the pension funds and post-retirement benefit plans do not hold any material investments in Emera or its subsidiaries securities. However, as a significant portion of assets for the benefit plan are held in pooled assets, there may be indirect investments in these securities.

 

CASH FLOWS

The following table shows the expected cash flows for defined benefit pension and other post-retirement benefit plans:

 

millions of Canadian dollars     Defined benefit
pension plans
    Non-pension
benefit plans
 
Expected employer contributions              
2021     $ 41     $ 19  
Expected benefit payments                  
2021       140       21  
2022       154       22  
2023       154       22  
2024       162       22  
2025       170       22  
2026–2030       914       105  

 

ASSUMPTIONS

The following table shows the assumptions that have been used in accounting for defined benefit pension and other post-retirement benefit plans:

 

    2020     2019  
(weighted average assumptions)   Defined benefit
pension plans
    Non-pension
benefit plans
    Defined benefit
pension plans
    Non-pension
benefit plans
 
Benefit obligation – December 31:                        
Discount rate – past service     2.49 %     2.48 %     3.17 %     3.27 %
Discount rate – future service     2.64 %     2.51 %     3.21 %     3.28 %
Rate of compensation increase     2.89 %     3.04 %     3.32 %     3.70 %
Health care trend – initial (next year)           5.64 %           6.15 %
  – ultimate           4.35 %           4.38 %
  – year ultimate reached             2038               2038  
Benefit cost for year ended December 31:                                
Discount rate – past service     3.17 %     3.28 %     4.05 %     4.30 %
Discount rate – future service     3.21 %     3.28 %     4.05 %     4.30 %
Expected long-term return on plan assets     6.29 %     3.25 %     6.50 %     2.81 %
Rate of compensation increase     3.34 %     3.70 %     3.30 %     3.67 %
Health care trend – initial (current year)           5.91 %           6.39 %
  – ultimate           4.37 %           4.45 %
  – year ultimate reached             2038               2035  

Actual assumptions used differ by plan.

 

The expected long-term rate of return on plan assets is based on historical and projected real rates of return for the plan’s current asset allocation, and assumed inflation. A real rate of return is determined for each asset class. Based on the asset allocation, an overall expected real rate of return for all assets is determined. The asset return assumption is equal to the overall real rate of return assumption added to the inflation assumption, adjusted for assumed expenses to be paid from the plan.

 

EMERA 2020 ANNUAL REPORT 135


 

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

The discount rate is based on high-quality long-term corporate bonds, with maturities matching the estimated cash flows from the pension plan.

 

DEFINED CONTRIBUTION PLAN

Emera also provides a defined contribution pension plan for certain employees. The Company’s contribution for the year ended December 31, 2020 was $45 million (2019 – $34 million).

 

22. GOODWILL

 

The change in goodwill for the year ended December 31 is due to the following:

 

millions of Canadian dollars   2020     2019  
Balance, January 1   $ 5,835     $ 6,313  
Additions           3  
GBPC impairment charge           (30 )
Classified as assets held for sale (1)           (148 )
Change in foreign exchange rate     (115 )     (303 )
Balance, December 31   $ 5,720     $ 5,835  
(1) On March 25, 2019, Emera announced the sale of Emera Maine. Emera Maine’s assets and liabilities were classified as held for sale. Refer to note 4 for further detail.

 

Goodwill is subject to an annual assessment for impairment at the reporting unit level. The goodwill on Emera’s Consolidated Balance Sheets at December 31, 2020, primarily relates to TECO Energy and GBPC. Emera’s reporting units with goodwill are Tampa Electric, PGS, NMGC, and GBPC.

 

In 2020, Emera performed a qualitative impairment assessment for Tampa Electric, PGS and NMGC, concluding that the fair value of the reporting units exceeded their respective carrying amounts, and as such, no quantitative assessment were performed and no impairment charges were recognized.

 

Goodwill on Emera’s Consolidated Balance Sheets at December 31, 2020, included $68 million (2019 – $70 million) related to GBPC. In 2019 Emera recognized an impairment charge of $30 million based on the excess of GBPC’s carrying amount over its fair value. The 2019 impairment charge is included in “Impairment charges” in the Consolidated Statements of Income. In 2020, due to the limited excess of fair value over carrying value as a result of the 2019 impairment charge, Emera elected to bypass a qualitative assessment and performed a quantitative impairment assessment using a discounted cash flow analysis. This assessment estimated that the fair value of the reporting unit exceeded its carrying value, including goodwill, by approximately five per cent. Adverse changes in significant assumptions used could result in a future impairment.

 

136 EMERA 2020 ANNUAL REPORT


 

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

23. SHORT-TERM DEBT

 

Emera’s short-term borrowings consist of commercial paper issuances, advances on revolving and non-revolving credit facilities and short-term notes. Short-term debt and the related weighted-average interest rates as at December 31 consisted of the following:

 

millions of Canadian dollars   2020     Weighted
average
interest rate
    2019     Weighted
average
interest rate
 
Tampa Electric Company (“TEC”)                                
Advances on accounts receivable and revolving credit facilities   $ 987       0.89 %   $ 452       2.56 %
Emera                                
Non-revolving term facility     400       0.94 %     399       2.69 %
Bank indebtedness           - %     6       - %
TECO Finance                                
Advances on revolving credit and term facilities     205       1.46 %     656       2.39 %
NMGC                                
Advances on revolving credit facilities     21       1.22 %     8       2.70 %
GBPC                                
Advances on revolving credit facilities     11       5.25 %     10       5.25 %
NSPI                                
Bank indebtedness     1       - %     6       - %
Short-term debt   $ 1,625             $ 1,537          

 

The Company’s total short-term revolving and non-revolving credit facilities, outstanding borrowings and available capacity as at December 31 were as follows:

 

millions of Canadian dollars   Maturity     2020     2019  
Tampa Electric Company – revolving credit facility     2023     $ 1,019     $ 520  
TECO Energy/TECO Finance – revolving credit facility     2023       509       520  
Emera – non-revolving term facility     2021       400       400  
TEC – term loan     2021       382        
TEC – accounts receivable revolving credit facility     2021       191       195  
NMGC – revolving credit facility     2023       159       162  
GBPC – revolving credit facility     on demand       17       17  
TECO Energy/TECO Finance – term credit facility                   649  
Total             2,677       2,463  
Less:                        
Advances under revolving credit and term facilities             1,624       1,525  
Letters of credit issued within the credit facilities             4       3  
Total advances under available facilities             1,628       1,528  
Available capacity under existing agreements           $ 1,049     $ 935  

 

The weighted average interest rate on outstanding short-term debt at December 31, 2020 was 1.01 per cent (2019 – 2.54 per cent).

 

EMERA 2020 ANNUAL REPORT 137


 

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

RECENT SIGNIFICANT FINANCING ACTIVITY BY SEGMENT

Florida Electric Utilities

On February 6, 2020, TEC entered into a $300 million USD non-revolving credit agreement with a maturity date of February 4, 2021. The credit agreement contains customary representations and warranties, events of default, financial and other covenants and bears interest at the London interbank deposit rate (“LIBOR”), prime rate or the federal funds rate, plus a margin. On January 29, 2021, TEC extended the maturity date of the agreement to April 29, 2021 with no other changes in terms.

 

On December 18, 2020, TEC amended and restated its bank credit facility. The amendment extended the maturity date of the credit facility from March 22, 2022 to March 22, 2023 and increased the amount of the commitment by the lenders to $800 million USD from $400 million USD. The credit facility bears interest based on either the LIBOR, the Wells Fargo Bank’s prime rate, or the federal funds rate, plus a margin. The amended facility now includes a $80 million USD letter of credit facility. There were no other significant changes in commercial terms from the prior agreement.

 

Gas Utilities and Infrastructure

On December 18, 2020, NMGC amended and restated its $125 million USD bank credit facility. The amendment extended the maturity date of the credit facility from March 22, 2022 to March 22, 2023. The credit facility bears interest based on either the LIBOR, JP Morgan Chase Bank’s prime rate, or the federal funds rate, plus a margin. The amended facility now includes a $30 million USD letter of credit facility. There were no other significant changes in commercial terms from the prior agreement.

 

Other

On February 28, 2020, TECO Finance extended the maturity date of its $500 million USD credit facility from March 5, 2020 to July 3, 2020. There were no other significant changes in commercial terms from the prior agreement. Using funds from the sale of Emera Maine, on April 3, 2020, TECO Finance repaid $200 million USD of the term loan and the remaining $300 million USD was repaid on June 30, 2020.

 

On December 1, 2020, Emera extended the maturity date of its $400 million non-revolving term loan from December 15, 2020 to December 16, 2021. There were no other significant changes in commercial terms from the prior agreement.

 

On December 18, 2020, TECO Finance amended and restated its $400 million USD bank credit facility. The amendment extended the maturity date of the credit facility from March 22, 2022 to March 22, 2023. The credit facility bears interest based on either the LIBOR, JP Morgan Chase Bank’s prime rate, or the federal funds rate, plus a margin. The facility now includes a $50 million USD letter of credit facility. There were no other significant changes in commercial terms from the prior agreement.

 

24. OTHER CURRENT LIABILITIES

 

As at
millions of Canadian dollars
  December 31
2020
    December 31
2019
 
Accrued charges   $ 141     $ 147  
Accrued interest on long-term debt     71       77  
Pension and post-retirement liabilities (note 21)     23       22  
Sales and other taxes payable     6       13  
Income tax payable     1       1  
Other     98       73  
    $ 340     $ 333  

 

25. LONG-TERM DEBT

 

Bonds, notes and debentures are at fixed interest rates and are unsecured unless noted below. Included are certain bankers’ acceptances and commercial paper where the Company has the intention and the unencumbered ability to refinance the obligations for a period greater than one year.

 

138 EMERA 2020 ANNUAL REPORT


 

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

Long-term debt as at December 31 consisted of the following:

 

    Weighted average
interest rate
(1)                  
millions of Canadian dollars   2020     2019     Maturity     2020     2019  
Emera                              
Bankers acceptances, LIBOR loans     Variable       Variable       2024     $ 263     $ 437  
Unsecured fixed rate notes     2.90 %     2.90 %     2023       500       500  
Fixed to floating subordinated notes (USD)     6.75 %     6.75 %     2076       1,528       1,559  
                            $ 2,291     $ 2,496  
Emera Finance                                        
Unsecured senior notes (USD)     3.86 %     3.86 %     2021–2046     $ 3,501     $ 3,572  
TECO Finance                                        
Fixed rate notes and bonds (USD)           5.15 %                 390  
Tampa Electric (2)                                        
Fixed rate notes and bonds (USD)     4.53 %     4.53 %     2021–2050     $ 3,268     $ 3,334  
PGS                                        
Fixed rate notes and bonds (USD)     4.58 %     4.58 %     2021–2050     $ 429     $ 437  
NMGC                                        
Fixed rate notes and bonds (USD)     4.30 %     4.30 %     2021–2049     $ 465     $ 474  
NMGI                                        
Fixed rate notes and bonds (USD)     3.64 %     3.64 %     2024     $ 191     $ 195  
NSPI                                        
Discount notes     Variable       Variable       2024     $ 291     $ 308  
Medium term fixed rate notes     5.14 %     5.37 %     2025–2097       2,665       2,365  
                            $ 2,956     $ 2,673  
Emera Maine                                        
LIBOR loans and demand loans         Variable         $     $ 11  
Secured fixed rate mortgage bonds (USD)           9.74 %                 65  
Unsecured senior fixed rate notes (USD)           4.15 %                 442  
                    $     $ 518  
EBP                                        
Senior secured credit facility     Variable       Variable       2023     $ 249     $ 248  
ECI                                        
Secured senior notes (USD)     Variable       Variable       2021–2031       106       130  
Amortizing fixed rate notes (USD)     3.92 %     3.89 %     2021–2022       100       122  
Non-revolving term facility, floating rate     Variable       -       2025       28        
Non-revolving term facility, fixed rate     2.60 %     -       2025       68        
Secured fixed rate senior notes (3)     4.39 %     4.84 %     2022–2035     $ 174     $ 218  
                            $ 476     $ 470  
Adjustments                                        
Fair market value adjustment – TECO Energy acquisition (4)                           $ 5     $ 8  
Debt issuance costs                             (110 )     (119 )
Classification as liabilities held for sale (5)                                   (516 )
Amount due within one year                             (1,382 )     (501 )
                            $ (1,487 )   $ (1,128 )
Long-Term Debt                           $ 12,339     $ 13,679  

(1) Weighted average interest rate of fixed rate long-term debt.

(2) A substantial part of Tampa Electric’s tangible assets are pledged as collateral to secure its first mortgage bonds. There are currently no bonds outstanding under Tampa Electric’s first mortgage bond indenture.

(3) Notes are issued and payable in either USD, BBD or East Caribbean Dollar (XCD).

(4) On acquisition of TECO Energy, Emera recorded a fair market value adjustment on the unregulated long-term debt acquired. The fair market value adjustment is amortized over the remaining term of the debt.

(5) On March 24, 2020 Emera sold Emera Maine. Refer to note 4 for further detail. As at December 31, 2019, Emera Maine’s assets and liabilities are classified as held for sale.

 

EMERA 2020 ANNUAL REPORT 139


 

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

The Company’s total long-term revolving credit facilities, outstanding borrowings and available capacity as at December 31 were as follows:

 

millions of Canadian dollars   Maturity     2020     2019  
Emera – revolving credit facility (1)   June 2024     $ 900     $ 900  
NSPI – revolving credit facility (1)   October 2024       600       600  
ECI – revolving credit facilities   2021–2023       28       25  
Emera Maine – revolving credit facility           -       104  
Total           1,528       1,629  
Less:                      
Borrowings under credit facilities           569       771  
Letters of credit issued inside credit facilities           31       65  
Use of available facilities           600       836  
Available capacity under existing agreements         $ 928     $ 793  
(1) Advances on the revolving credit facility can be made by way of overdraft on accounts up to $50 million.

 

DEBT COVENANTS

Emera and its subsidiaries have debt covenants associated with their credit facilities. Covenants are tested regularly and the Company is in compliance with covenant requirements. Emera’s significant covenants are listed below:

 

            As at
    Financial Covenant   Requirement   December 31, 2020
Emera            
Syndicated credit facilities   Debt to capital ratio   Less than or equal to 0.70 to 1   0.56 : 1

 

RECENT SIGNIFICANT FINANCING ACTIVITY BY SEGMENT

 

Canadian Electric Utilities

On April 24, 2020, NSPI completed a $300 million 30-year unsecured notes issuance. The notes bear interest at a rate of 3.31 per cent and have a maturity date of April 25, 2050.

 

Other Electric Utilities

On May 20, 2020, GBPC entered into a $22 million USD non-revolving term loan with a maturity date of May 20, 2025. The loan bears interest at a rate of 90-day LIBOR plus a margin. On May 22, 2020, proceeds from this loan were used to repay $22 million USD senior notes upon maturity.

 

On May 20, 2020, GBPC entered into a $15 million BSD ($15 million USD) non-revolving term loan with a maturity date of May 20, 2025. The loan bears interest at a rate of 4.00 per cent.

 

At December 31, 2020, BLPC had drawn $77 million BBD ($38 million USD) against a $110 million BBD ($55 million USD) non-revolving term loan. The loan bears interest at a rate of 2.05 per cent and has a 5-year term.

 

Gas Utilities and Infrastructure

On February 5, 2021, NMGC completed an issuance of $220 million USD senior notes. The issuance included $70 million USD senior notes that bear interest at a rate of 2.26 per cent with a maturity date of February 5, 2031, $65 million USD senior notes that bear interest at a rate of 2.51 per cent and with a maturity date of February 5, 2036, and $85 million USD senior notes that bear interest at a rate of 3.34 per cent with a maturity date of February 5, 2051. Proceeds from this issuance were used to repay a $200 million USD note, due in 2021 and for general corporate purposes. These notes were classified as long-term debt at December 31, 2020.

 

Other

On March 13, 2020, TECO Finance repaid a $300 million USD note upon maturity. The note was repaid using existing credit facilities.

 

140 EMERA 2020 ANNUAL REPORT


 

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

LONG-TERM DEBT MATURITIES

As at December 31, long-term debt maturities, including capital lease obligations, for each of the next five years and in aggregate thereafter are as follows:

 

millions of Canadian dollars   2021     2022     2023     2024     2025     Thereafter     Total  
Emera   $     $     $ 500     $ 263     $     $ 1,528     $ 2,291  
Emera US Finance LP     955                               2,546       3,501  
Tampa Electric     295       286                         2,687       3,268  
PGS     59       33                         337       429  
NMGC                                   465       465  
NMGI                       191                   191  
NSPI                       291       125       2,540       2,956  
EBP                 249                         249  
ECI     73       88       60       75       101       79       476  
Total   $ 1,382     $ 407     $ 809     $ 820     $ 226     $ 10,182     $ 13,826  

 

26. ASSET RETIREMENT OBLIGATIONS

 

AROs mostly relate to reclamation of land at the thermal, hydro and combustion turbine sites; and the disposal of polychlorinated biphenyls in transmission and distribution equipment and a pipeline site. Certain hydro, transmission and distribution assets may have additional AROs that cannot be measured as these assets are expected to be used for an indefinite period and, as a result, a reasonable estimate of the fair value of any related ARO cannot be made.

 

The change in ARO for the years ended December 31 is as follows:

 

millions of Canadian dollars   2020     2019  
Balance, January 1   $ 185     $ 205  
Additions     10        
Liabilities settled (1)     (25 )     (25 )
Accretion included in depreciation expense     9       7  
Accretion deferred to regulatory asset (included in property, plant and equipment)     (3 )      
Other     1       3  
Change in foreign exchange rate     1       (5 )
Balance, December 31   $ 178     $ 185  
(1) Tampa Electric produces ash and other by-products, collectively known as CCR’s, at its Big Bend and Polk power stations. The decreases in ARO in 2020 and 2019 are due to the closure of CCR management facilities.

 

EMERA 2020 ANNUAL REPORT 141


 

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

27. COMMITMENTS AND CONTINGENCIES

 

A. COMMITMENTS

As at December 31, 2020, contractual commitments (excluding pensions and other post-retirement obligations, convertible debentures, long-term debt and asset retirement obligations) for each of the next five years and in aggregate thereafter consisted of the following:

 

millions of Canadian dollars   2021     2022     2023     2024     2025     Thereafter     Total  
Purchased power (1)   $ 231     $ 218     $ 216     $ 218     $ 224     $ 2,242     $ 3,349  
Transportation (2)     518       393       339       306       282       2,704       4,542  
Capital projects     394       98       76                         568  
Fuel, gas supply and storage     494       91       6       1                   592  
Long-term service agreements (3)     43       41       36       33       34       92       279  
Equity investment commitments (4)           240                               240  
Leases and other (5)     16       17       16       15       8       118       190  
Demand side management     40       45                               85  
    $ 1,736     $ 1,143     $ 689     $ 573     $ 548     $ 5,156     $ 9,845  
(1) Annual requirement to purchase electricity production from independent power producers or other utilities over varying contract lengths.
(2) Purchasing commitments for transportation of fuel and transportation capacity on various pipelines. Includes a commitment of $149 million related to a gas transportation contract between PGS and SeaCoast through 2040.

(3) Maintenance of certain generating equipment, services related to a generation facility and wind operating agreements, outsourced management of computer and communication infrastructure and vegetation management.

(4) Emera has a commitment to make equity contributions to the Labrador Island Link Limited Partnership.

(5) Includes operating lease agreements for buildings, land, telecommunications services and rail cars, transmission rights and investment commitments.

 

On March 17, 2020, Nalcor announced that it had paused construction activities at the Muskrat Falls site in response to the COVID-19 pandemic. As a result of the effects of COVID-19 on project execution, Nalcor declared force majeure under various project contracts, including formal notification to NSPML. Nalcor achieved first power on the first of four generators at Muskrat Falls on September 22, 2020 and continues to work toward completing project commissioning in 2021.

 

NSPML expects to file a final cost assessment with the UARB upon commencement of the NS Block of energy from Muskrat Falls, which is anticipated to take place in 2021. On December 16, 2020, the UARB approved NSPML’s 2021 interim assessment for recovery from NSPI of Maritime Link costs of approximately $172 million subject to a holdback of $10 million with similar terms as previously approved by the UARB and potential long-term deferral of up to $23 million in depreciation expense dependent upon the timing of commencement of the NS Block.

 

NSPI has a contractual obligation to pay NSPML for the use of the Maritime Link over approximately 38 years from its January 15, 2018 in-service date. As part of NSPI’s 2020-2022 fuel stability plan, rates have been set to include the $145 million approved for 2020 and amounts of $164 million and $162 million for 2021 and 2022, respectively. On December 16, 2020, the UARB approved the 2021 interim cost assessment of approximately $172 million. Any difference between the amounts included in the NSPI fuel stability plan and those approved by the UARB through the NSPML interim assessment application will be addressed through the FAM. The timing and amounts payable to NSPML for the remainder of the 38-year commitment period are dependent on regulatory filings with the UARB.

 

Once Muskrat Falls and LIL have achieved full power, the commercial agreements between Emera and Nalcor require true ups to finalize the respective investment obligations of the parties relating to the Maritime Link and LIL.

 

Emera has committed to obtain certain transmission rights for Nalcor Energy, if requested, to enable them to transmit energy which is not otherwise used in Newfoundland or Nova Scotia. This energy could be transmitted from Nova Scotia to New England energy markets beginning at first commercial power of the Muskrat Falls hydroelectric generating facility and related transmission assets when Nalcor commences delivery of the NS Block, and continuing for 50 years. As transmission rights are contracted, the obligations are included within “Leases and other” in the above table.

 

142 EMERA 2020 ANNUAL REPORT


 

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

B. LEGAL PROCEEDINGS

 

TECO Guatemala Holdings (“TGH”) 

Prior to Emera’s acquisition of TECO Energy in 2016, TGH, a wholly owned subsidiary of TECO Energy, divested of its indirect investment that resided in Guatemala. In 2013, the ICSID tribunal hearing an arbitration claim of TGH against the Republic of Guatemala (“Guatemala”) under the Dominican Republic Central America – United States Free Trade Agreement, issued an award. The arbitration concerned TGH’s allegation that Guatemala unfairly set the distribution tariff for a local distribution company which harmed TGH’s investment in that company. The ICSID Tribunal unanimously found in favour of TGH and awarded damages to TGH of approximately $21 million USD, plus interest from October 21, 2010 at a rate equal to the U.S. prime rate plus 2 per cent. Subsequent proceedings resulted in Guatemala awards of additional interest and certain costs to TGH (in aggregate, the “First Award”). In November 2020, Guatemala withdrew its appeal in U.S. courts against the enforcement of the First Award and made a payment of approximately $38 million USD in full and final satisfaction of the First Award. This amount was recognized in “Other Income, net” on the Consolidated Statements of Income.

 

On September 23, 2016, TGH had filed a separate request for resubmission to arbitration seeking damages in addition to those awarded in the First Award. On May 13, 2020, a second tribunal awarded TGH additional damages and costs against Guatemala of more than $35 million USD plus interest (the “Second Award”). TGH subsequently requested a reconsideration of the interest quantum awarded in connection with this Second Award. On October 16, 2020, the tribunal granted TGH’s request for additional interest. The additional amount is approximately $2 million USD. Guatemala now has until February 16, 2021 to seek annulment of the Second Award before ICSID. To date, the total of the Second Award, with interest, is approximately $59 million USD. Results to date do not reflect any benefit of the Second Award.

 

Superfund and Former Manufactured Gas Plant Sites 

TEC, through its Tampa Electric and PGS divisions, is a potentially responsible party (“PRP”) for certain superfund sites and, through its PGS division, for certain former manufactured gas plant sites. While the joint and several liability associated with these sites presents the potential for significant response costs, as at December 31, 2020, TEC has estimated its financial liability to be $22 million ($17 million USD), primarily at PGS. This estimate assumes that other involved PRPs are credit-worthy entities. This amount has been accrued and is primarily reflected in the long-term liability section under “Other long-term liabilities” on the Consolidated Balance Sheets. The environmental remediation costs associated with these sites are expected to be paid over many years.

 

The estimated amounts represent only the portion of the cleanup costs attributable to TEC. The estimates to perform the work are based on TEC’s experience with similar work, adjusted for site-specific conditions and agreements with the respective governmental agencies. The estimates are made in current dollars, are not discounted and do not assume any insurance recoveries.

 

In instances where other PRPs are involved, most of those PRPs are believed to be currently credit-worthy and are likely to continue to be credit-worthy for the duration of the remediation work. However, in those instances that they are not, TEC could be liable for more than TEC’s actual percentage of the remediation costs. Other factors that could impact these estimates include additional testing and investigation which could expand the scope of the cleanup activities, additional liability that might arise from the cleanup activities themselves or changes in laws or regulations that could require additional remediation. Under current regulations, these costs are recoverable through customer rates established in base rate proceedings.

 

Emera Maine 

On March 24, 2020, the Company completed the sale of Emera Maine. Emera has no remaining obligations with respect to the legal proceedings previously disclosed in note 26 of Emera’s 2019 annual audited consolidated financial statements. No new or additional reserves were made in 2020 with respect to any of the four complaints filed with the FERC.

 

Other Legal Proceedings 

Emera and its subsidiaries may, from time to time, be involved in other legal proceedings, claims and litigation that arise in the ordinary course of business which the Company believes would not reasonably be expected to have a material adverse effect on the financial condition of the Company.

 

EMERA 2020 ANNUAL REPORT 143


 

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

C. PRINCIPAL FINANCIAL RISKS AND UNCERTAINTIES 

Emera believes the following principal financial risks could materially affect the Company in the normal course of business. Risks associated with derivative instruments and fair value measurements are discussed in note 15 and note 16.

 

Sound risk management is an essential discipline for running the business efficiently and pursuing the Company’s strategy successfully. Emera has a business-wide risk management process, monitored by the Board of Directors, to ensure a consistent and coherent approach to risk management.

 

Public Health Risk 

An outbreak of infectious disease, a pandemic or a similar public health threat, such as the COVID-19 pandemic, or a fear of any of the foregoing, could adversely impact the Company, including causing operating, supply chain and project development delays and disruptions, labour shortages and shutdowns (including as a result of government regulation and prevention measures), which could have a negative impact on the Company’s operations.

 

Any adverse changes in general economic and market conditions arising as a result of a public health threat could negatively impact demand for electricity and natural gas, revenue, operating costs, timing and extent of capital expenditures, results of financing efforts, or credit risk and counterparty risk; which could result in a material adverse effect on the Company’s business.

 

The extent of the evolving COVID-19 pandemic and its future impact on the Company is uncertain. The Company maintains pandemic and business contingency plans in each of its operations to manage and help mitigate the impact of any such public health threat. The Company’s top priority continues to be the health and safety of its customers and employees.

 

Foreign Exchange Risk 

The Company is exposed to foreign currency exchange rate changes. Emera operates internationally, with an increasing amount of the Company’s adjusted net income earned outside of Canada. As such, Emera is exposed to movements in exchange rates between the Canadian dollar and, particularly, the US dollar, which could positively or adversely affect results.

 

Consistent with the Company’s risk management policies, Emera manages currency risks through matching US denominated debt to finance its US operations and may use foreign currency derivative instruments to hedge specific transactions and earnings exposure. The Company may enter into foreign exchange forward and swap contracts to limit exposure on certain foreign currency transactions such as fuel purchases, revenues streams and capital expenditures, and on net income earned outside of Canada. The regulatory framework for the Company’s rate-regulated subsidiaries permits the recovery of prudently incurred costs, including foreign exchange.

 

The Company does not utilize derivative financial instruments for foreign currency trading or speculative purposes or to hedge the value of its investments in foreign subsidiaries. Exchange gains and losses on net investments in foreign subsidiaries do not impact net income as they are reported in AOCI.

 

Liquidity and Capital Market Risk 

Liquidity risk relates to Emera’s ability to ensure sufficient funds are available to meet its financial obligations. Emera manages this risk by forecasting cash requirements on a continuous basis to determine whether sufficient funds are available. Liquidity and capital needs could be financed through internally generated cash flows, asset sales, short-term credit facilities, and ongoing access to capital markets. The Company reasonably expects liquidity sources to exceed capital needs.

 

Emera’s access to capital and cost of borrowing is subject to several risk factors, including financial market conditions, market disruptions and ratings assigned by credit rating agencies. Disruptions in capital markets could prevent Emera from issuing new securities or cause the Company to issue securities with less than preferred terms and conditions. Emera’s growth plan requires significant capital investments in property, plant and equipment and the risk associated with changes in interest rates could have an adverse effect on the cost of financing. The inability to access cost-effective capital could have a material impact on Emera’s ability to fund its growth plan. The Company’s future access to capital and cost of borrowing may be impacted by various market disruptions including those related to public health threats, such as the COVID-19 pandemic.

 

144 EMERA 2020 ANNUAL REPORT


 

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

Emera is subject to financial risk associated with changes in its credit ratings. There are a number of factors that rating agencies evaluate to determine credit ratings, including the Company’s business and regulatory framework, the ability to recover costs and earn returns, diversification, leverage, liquidity and increased exposure to climate change-related impacts, including increased frequency and severity of hurricanes and other severe weather events. A decrease in a credit rating could result in higher interest rates in future financings, increase borrowing costs under certain existing credit facilities, limit access to the commercial paper market or limit the availability of adequate credit support for subsidiary operations. For certain derivative instruments, if the credit ratings of the Company were reduced below investment grade, the full value of the net liability of these positions could be required to be posted as collateral. Emera manages these risks by actively monitoring and managing key financial metrics with the objective of sustaining investment grade credit ratings.

 

The Company has exposure to its own common share price through the issuance of various forms of stock-based compensation, which affect earnings through revaluation of the outstanding units every period. The Company uses equity derivatives to reduce the earnings volatility derived from stock-based compensation.

 

Interest Rate Risk 

Emera utilizes a combination of fixed and floating rate debt financing for operations and capital expenditures, resulting in an exposure to interest rate risk. Emera seeks to manage interest rate risk through a portfolio approach that includes the use of fixed and floating rate debt with staggered maturities. The Company will, from time to time, issue long-term debt or enter interest rate hedging contracts to limit its exposure to fluctuations in floating interest rate debt. Interest rates may be impacted by market disruptions related to public health threats, including the COVID-19 pandemic.

 

For Emera’s regulated subsidiaries, the cost of debt is a component of rates and prudently incurred debt costs are recovered from customers. Regulatory ROE will generally follow the direction of interest rates, such that regulatory ROE’s are likely to fall in times of reducing interest rates and rise in times of increasing interest rates, albeit not directly and generally with a lag period reflecting the regulatory process. Rising interest rates may also negatively affect the economic viability of project development and acquisition initiatives.

 

Commodity Price Risk 

The Company’s utility fuel supply is subject to commodity price risk. In addition, Emera Energy is subject to commodity price risk through its portfolio of commodity contracts and arrangements.

 

The Company manages this risk through established processes and practices to identify, monitor, report and mitigate these risks. The Company’s commercial arrangements, including the combination of supply and purchase agreements, asset management agreements, pipeline transportation agreements and financial hedging instruments are all used to manage and mitigate this risk. In addition, its credit policies, counterparty credit assessments, market and credit position reporting, and other risk management and reporting practices, are also used to manage and mitigate this risk.

 

Regulated Utilities 

A large portion of the Company’s utility fuel supply comes from international suppliers and therefore may be exposed to broader global conditions, which may include impacts on delivery reliability and price, despite contracted terms. The Company seeks to manage this risk using financial hedging instruments and physical contracts and through contractual protection with counterparties, where applicable.

 

The majority of Emera’s regulated utilities have adopted and implemented fuel adjustment mechanisms which has further helped manage commodity price risk, as the regulatory framework for the Company’s rate-regulated subsidiaries permits the recovery of prudently incurred fuel costs.

 

EMERA 2020 ANNUAL REPORT 145


 

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

Emera Energy Marketing and Trading 

Emera Energy has employed further measures to manage commodity risk. The majority of Emera’s portfolio of electricity and gas marketing and trading contracts and, in particular, its natural gas asset management arrangements, are contracted on a back-to-back basis, avoiding any material long or short commodity positions. However, the portfolio is subject to commodity price risk, particularly with respect to basis point differentials between relevant markets, in the event of an operational issue or counterparty default.

 

To measure commodity price risk exposure, Emera employs a number of controls and processes, including an estimated value-at-risk (“VaR”) analysis of its exposures. The VaR amount represents an estimate of the potential change in fair value that could occur from changes in market factors within a given confidence level, if an instrument or portfolio is held for a specified time period. The VaR calculation is used to quantify exposure to market risk associated with physical commodities, primarily natural gas and power positions.

 

Income Tax Risk 

The computation of the Company’s provision for income taxes is impacted by changes in tax legislation in Canada, the United States and the Caribbean. Any such changes could affect the Company’s future earnings, cash flows, and financial position. The value of Emera’s existing deferred tax assets and liabilities are determined by existing tax laws and could be negatively impacted by changes in laws. Emera monitors the status of existing tax laws to ensure that changes impacting the Company are appropriately reflected in the Company’s tax compliance filings and financial results.

 

D. GUARANTEES AND LETTERS OF CREDIT 

Emera has guarantees and letters of credit on behalf of third parties outstanding. The following significant guarantees and letters of credit are not included within the Consolidated Balance Sheets as at December 31, 2020:

 

TECO Energy has issued a guarantee in connection with SeaCoast’s performance of obligations under a gas transportation precedent agreement. The guarantee is for a maximum potential amount of $45 million USD if SeaCoast fails to pay or perform under the contract. The guarantee expires five years after the gas transportation precedent agreement termination date, which is expected to terminate on January 1, 2022. In the event that TECO Energy’s and Emera’s long-term senior unsecured credit ratings are downgraded below investment grade by Moody’s or S&P, TECO Energy would be required to provide its counterparty a letter of credit or cash deposit of $27 million USD.

 

Emera Inc. has issued a guarantee of up to $35 million USD relating to outstanding notes of GBPC. The guarantee for the notes will expire in May 2023.

 

In 2020, NSPI issued guarantees in the amount of $18 million USD on behalf of its subsidiary, NS Power Energy Marketing Incorporate (“NSPEMI”), to secure obligations under purchase agreements with third-party suppliers. The guarantees have terms of varying lengths and will be renewed as required.

 

The Company has standby letters of credit and surety bonds in the amount of $55 million USD (December 31, 2019 – $82 million USD) to third parties that have extended credit to Emera and its subsidiaries. These letters of credit and surety bonds typically have a one-year term and are renewed annually as required.

 

Emera Inc., on behalf of NSPI, has a standby letter of credit to secure obligations under a supplementary retirement plan. The expiry date of this letter of credit was extended to June 2021. The amount committed as at December 31, 2020 was $63 million (December 31, 2019 – $52 million).

 

146 EMERA 2020 ANNUAL REPORT


 

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

Collaborative Arrangements 

For the years ended December 31, 2020 and 2019, the Company has identified the following material collaborative arrangements:

 

Through NSPI, the Company is a participant in three wind energy projects in Nova Scotia. The percentage ownership of the wind project assets is based on the relative value of each party’s project assets by the total project assets. NSPI has power purchase arrangements to purchase the entire net output of the projects and, therefore, NSPI’s portion of the revenues are recorded net within regulated fuel for generation and purchased power. NSPI’s portion of operating expenses is recorded in OM&G expenses. In 2020, NSPI recognized $19 million net expense (2019 – $19 million) in “Regulated fuel for generation and purchased power” and $3 million (2019 – $3 million) in OM&G.

 

28. CUMULATIVE PREFERRED STOCK

 

Authorized: 

Unlimited number of First Preferred shares, issuable in series.

 

Unlimited number of Second Preferred shares, issuable in series.

 

                December 31, 2020     December 31, 2019  
    Annual Dividend       Redemption       Issued and       Net       Issued and       Net  
      per Share       Price per Share       Outstanding       Proceeds       Outstanding       Proceeds  
Series A   $ 0.6388     $ 25.00       4,866,814     $ 95       3,864,636     $ 95  
Series B     Floating     $ 25.00       1,133,186     $ 52       2,135,364     $ 52  
Series C   $ 1.1802     $ 25.00       10,000,000     $ 245       10,000,000     $ 245  
Series E   $ 1.1250     $ 25.75       5,000,000     $ 122       5,000,000     $ 122  
Series F   $ 1.0625     $ 25.00       8,000,000     $ 195       8,000,000     $ 195  
Series H   $ 1.2250     $ 25.00       12,000,000     $ 295       12,000,000     $ 295  
Total                     41,000,000     $ 1,004       41,000,000     $ 1,004  

 

EMERA 2020 ANNUAL REPORT 147


 

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

Characteristics of the First Preferred Shares:

 

First Preferred Shares (1) (2)   Initial
Yield
(%)
    Current
Annual
Dividend
($)
    Minimum
Reset
Dividend Yield
(%)
    Earliest Redemption
and/or Conversion
Option Date
  Redemption
Value
($)
    Right to
Convert on
a One for
One Basis
Fixed rate reset (3) (4)
Series A (5) (6)     4.400       0.5456       1.84     August 15, 2025     25.00     Series B
Series C     4.100       1.1802       2.65     August 15, 2023     25.00     Series D
Series F (7) (8)     4.202       1.0505       2.63     February 15, 2025     25.00     Series G
Minimum rate reset (3) (4)
Series B (9)     2.393       Floating       1.84     August 15, 2025     25.00     Series A
Series H     4.900       1.2250       4.90     August 15, 2023     25.00     Series I
Perpetual fixed rate                                        
Series E (10)     4.500       1.1250                   25.75      
(1) Holders are entitled to receive fixed or floating cumulative cash dividends when declared by the Board of Directors of the Corporation.

(2) On or after the specified redemption dates, the Corporation has the option to redeem for cash the outstanding First Preferred Shares, in whole or in part, at the specified per share redemption value plus all accrued and unpaid dividends up to but excluding the dates fixed for redemption.

(3) On the redemption and/or conversion option date the reset annual dividend per share will be determined by multiplying $25.00 per share by the annual fixed or floating dividend rate, which for Series A, C, F and H is the sum of the five-year Government of Canada Bond Yield on the applicable reset date, plus the applicable reset dividend yield (Series H annual reset rate must be a minimum of 4.90 per cent) and for Series B equals the Government of Treasury Bill Rate on the applicable reset date, plus 1.84 per cent.

(4) On each conversion option date, the holders have the option, subject to certain conditions, to convert any or all of their Shares into an equal number of Cumulative Redeemable First Preferred Shares of a specified series. The Company has the right to redeem the outstanding Preferred Shares, Series D, Series G and Series I shares without the consent of the holder every five years thereafter for cash, in whole or in part at a price of $25.00 per share plus all accrued and unpaid dividends up to but excluding the date fixed for redemption and $25.50 per share plus all accrued and unpaid dividends up to but excluding the date fixed for redemption in the case of redemptions on any other date after August 15, 2023, February 15, 2020 and August 15, 2023, respectively. The reset dividend yield for Series I equals the Government of Treasury Bill Rate on the applicable reset date, plus 2.54 per cent.

(5) The annual fixed dividend per share for First Preferred Shares, Series A was reset from $0.6388 to $0.5456 for the five-year period from and including August 15, 2020.

(6) On July 9, 2020, Emera announced it would not redeem the Cumulative Rate Reset Preferred Shares, Series A or the Cumulative Floating Rate First Preferred Shares, Series B. On August 17, 2020, Emera announced 128,610 of its 3,864,636 issued and outstanding Series A Shares were tendered for conversion into Series B Shares and 1,130,788 of its 2,135,364 issued and outstanding Series B Shares were tendered for conversion into Series A Shares, all on a one-for-one basis. As a result of the conversion, Emera has 4,866,814 Series A Shares and 1,133,186 Series B Shares issued and outstanding.

(7) On January 7, 2020, Emera announced it would not redeem the 8,000,000 Cumulative Rate Reset First Preferred Shares, Series F Shares. The holders of the Series F Shares have the right, at their option, to convert all or any of their Series F Shares, on a one-for-one basis, into Cumulative Floating Rate First Preferred Shares, Series G of the Company on February 15, 2020, or to continue to hold their Series F Shares. On February 6, 2020, Emera announced that, after having taken into account all conversion notices received from holders, no First Preferred Shares, Series F Shares would be converted into Cumulative Floating Rate First Preferred Shares, Series G Shares.

(8) The annual fixed dividend per share for First Preferred Shares, Series F was reset from $1.0625 to $1.0505 for the five-year period from and including February 15, 2020.

(9) Emera announced a dividend rate of 2.021 per cent on the Series B Shares for the three-month period which commenced on August 15, 2020 and ended on (and inclusive of) November 14, 2020 ($0.1274 per Series B Share for the quarter.

(10) First Preferred Shares, Series E are redeemable at $25.75 to August 15, 2020, decreasing $0.25 each year until August 15, 2022 and $25.00 per share thereafter.

 

First Preferred Shares are neither redeemable at the option of the shareholder nor have a mandatory redemption date. They are classified as equity and the associated dividends is deducted on the Consolidated Statements of Income before arriving at “Net earnings attributable to common shareholders” and is shown on the Consolidated Statement of Equity as a deduction from retained earnings.

 

The First Preferred Shares of each series rank on a parity with the First Preferred Shares of every other series and are entitled to a preference over the Second Preferred Shares, the Common Shares, and any other shares ranking junior to the First Preferred Shares with respect to the payment of dividends and the distribution of the remaining property and assets or return of capital of the Company in the liquidation, dissolution or wind-up, whether voluntary or involuntary.

 

In the event the Company fails to pay, in aggregate, eight quarterly dividends on any series of the First Preferred Shares, the holders of the First Preferred Shares, for only so long as the dividends remain in arrears, will be entitled to attend any meeting of shareholders of the Company at which directors are to be elected and to vote for the election of two directors out of the total number of directors elected at any such meeting.

 

148 EMERA 2020 ANNUAL REPORT


 

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

29. NON-CONTROLLING INTEREST IN SUBSIDIARIES

 

As at   December 31     December 31  
millions of Canadian dollars   2020     2019  
Preferred shares of GBPC   $ 14     $ 14  
Domlec     20       21  
    $ 34     $ 35  

 

PREFERRED SHARES OF GBPC: 

Authorized: 

10,000 non-voting cumulative redeemable variable perpetual preferred shares.

 

          2020           2019  
      number of       millions of       number of       millions of  
Issued and outstanding:     shares       dollars       shares       dollars  
Outstanding as at December 31     10,000     $ 14       10,000     $ 14  

 

GBPC NON–VOTING CUMULATIVE VARIABLE PERPETUAL PREFERRED STOCK: 

The preferred shares are redeemable by GBPC after June 17, 2021, at $1,000 Bahamian per share plus accrued and unpaid dividends and are entitled to a 6.0 per cent per annum fixed cumulative preferential dividend to be paid semi-annually.

 

The Preferred Shares rank behind GBPC’s current and future secured and unsecured debt and ahead of all of GBPC’s current and future common stock.

 

30. SUPPLEMENTARY INFORMATION TO CONSOLIDATED STATEMENTS OF CASH FLOWS

 

For the   Year ended December 31  
millions of Canadian dollars     2020       2019  
Changes in non-cash working capital:                
Inventory   $ 6     $ (19 )
Receivables and other current assets     187       154  
Accounts payable     55       (137 )
Other current liabilities     (31 )     (71 )
Total non-cash working capital   $ 217     $ (73 )
                 
Supplemental disclosure of cash paid (received):                
Interest   $ 679     $ 750  
Income taxes   $ (148 )   $ (107 )
Supplemental disclosure of non-cash activities:                
Common share dividends reinvested   $ 199     $ 187  
Reclassification of long-term debt from current to non-current   $ 256     $  
Increase in accrued capital expenditures   $ 17     $ 33  

 

EMERA 2020 ANNUAL REPORT 149


 

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

31. STOCK-BASED COMPENSATION

 

EMPLOYEE COMMON SHARE PURCHASE PLAN AND COMMON SHAREHOLDERS DIVIDEND REINVESTMENT AND SHARE PURCHASE PLAN 

Eligible employees may participate in Emera’s Employee Common Share Purchase Plan. As of December 31, 2020, the plan allows employees to make cash contributions of a minimum of $25 to a maximum of $20,000 Canadian dollars or $15,000 US dollars per year for the purpose of purchasing common shares of Emera. The Company also contributes 20 per cent of the employees’ contributions to the plan.

 

The plan allows the reinvestment of dividends for all participants except for where it is prohibited by law. The maximum aggregate number of Emera common shares reserved for issuance under this plan is 7 million common shares (2019 – 4 million common shares). As at December 31, 2020, Emera is in compliance with this requirement.

 

Compensation cost for shares issued by Emera for the year ended December 31, 2020 under the Employee Common Share Purchase Plan was $2 million (2019 – $1 million) and is included in OM&G on the Consolidated Statements of Income.

 

The Company also has a Common Shareholders Dividend Reinvestment and Share Purchase Plan (“Dividend Reinvestment Plan”) or (“DRIP”), which provides an opportunity for shareholders to reinvest dividends and purchase common shares. This plan provides for a discount of up to 5 per cent from the average market price of Emera’s common shares for common shares purchased in connection with the reinvestment of cash dividends. The discount was 2 per cent in 2020. Effective with the dividend payment of August 15, 2019, the discount changed from 5 per cent to 2 per cent.

 

STOCK-BASED COMPENSATION PLANS 

Stock Option Plan 

The Company has a stock option plan that grants options to senior management of the Company for a maximum term of 10 years. The option price of the stock options is the closing market price of the stocks on the day before the option is granted. The maximum aggregate number of shares issuable under this plan is 11.7 million shares. As at December 31, 2020, Emera is in compliance with this requirement.

 

Stock options vest in 25 per cent increments on the first, second, third and fourth anniversaries of the date of the grant. If an option is not exercised within 10 years, it expires and the optionee loses all rights thereunder. The holder of the option has no rights as a shareholder until the option is exercised and shares have been issued. The total number of stocks to be optioned to any optionee shall not exceed five per cent of the issued and outstanding common stocks on the date the option is granted.

 

Unless a stock option has expired, vested options may be exercised within the 24 months following the option holders date of retirement or termination for other than just cause, and within six months following the date of termination for just cause, resignation or death. If stock options are not exercised within such time, they expire.

 

The Company uses the Black-Scholes valuation model to estimate the compensation expense related to its stock-based compensation and recognizes the expense over the vesting period on a straight-line basis.

 

The following table shows the weighted average fair values per stock option along with the assumptions incorporated into the valuation models for options granted, for the year-ended December 31:

 

    2020     2019  
Weighted average fair value per option   $ 3.58     $ 2.41  
Expected term (1)     5 years       6 years  
Risk-free interest rate (2)     1.33 %     1.82 %
Expected dividend yield (3)     4.09 %     5.10 %
Expected volatility (4)     14.10 %     14.32 %
(1) The expected term of the option awards is calculated based on historical exercise behaviour and represents the period of time that the options are expected to be outstanding.

(2) Based on the Bank of Canada five-year government bond yields.

(3) Incorporates current dividend rates and historical dividend increase patterns.

(4) Estimated using the five-year historical volatility.

 

150 EMERA 2020 ANNUAL REPORT


 

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

The following table summarizes stock option information for 2020:

 

      Total Options     Non-Vested Options (1)  
      Number of
Options
    Weighted
Average
Exercise Price
per Share
    Number of
Options
    Weighted
Average Grant
Date Fair Value
 
Outstanding as at December 31, 2019       2,286,550     $ 43.31       1,549,025     $ 2.22  
Granted       501,900       60.03       501,900       3.58  
Exercised       (417,968 )     44.74       N/A       N/A  
Vested       N/A       N/A       (654,375 )     2.32  
Forfeited       (102,700 )     45.94       (102,700 )     2.33  
Options outstanding December 31, 2020       2,267,782     $ 46.62       1,293,850     $ 2.69  
Options exercisable December 31, 2020 (2) (3)       973,932     $ 42.08                  
(1) As at December 31, 2020, there was $2 million of unrecognized compensation related to stock options not yet vested which is expected to be recognized over a weighted average period of approximately 3 years (2019 – $2 million, 2 years).

(2) As at December 31, 2020, the weighted average remaining term of vested options was 6 years with an aggregate intrinsic value of $12 million (2019 – 6 years, $11 million).

(3) As at December 31, 2020, the fair value of options that vested in the year was $2 million (2019 – $2 million).

 

Compensation cost recognized for stock options for the year ended December 31, 2020 was $1 million (2019 – $1 million), which is included in OM&G on the Consolidated Statements of Income.

 

As at December 31, 2020, cash received from option exercises was $19 million (2019 – $97 million). The total intrinsic value of options exercised for the year ended December 31, 2020 was $6 million (2019 – $32 million). The range of exercise prices for the options outstanding as at December 31, 2020 was $32.06 to $60.03 (2019 – $32.06 to $46.39).

 

SHARE UNIT PLANS 

The Company has Deferred Share Unit Plan (“DSU”), Performance Share Unit Plan (“PSU”) and Restricted Share Unit Plan (“RSU”) plans and the liabilities are marked-to-market at the end of each period based on an average common share price at the end of the period.

 

Deferred Share Unit Plans 

Under the Directors’ DSU plan, Directors of the Company may elect to receive all or any portion of their compensation in DSUs in lieu of cash compensation, subject to requirements to receive a minimum portion of their annual retainer in DSUs. Directors’ fees are paid on a quarterly basis and, at the time of each payment of fees, the applicable amount is converted to DSUs. A DSU has a value equal to one Emera common share. When a dividend is paid on Emera’s common shares, the Director’s DSU account is credited with additional DSUs. DSUs cannot be redeemed for cash until the Director retires, resigns or otherwise leaves the Board. The cash redemption value of a DSU equals the market value of a common share at the time of redemption, pursuant to the plan. Following retirement or resignation from the Board, the value of the DSUs credited to the participant’s account is calculated by multiplying the number of DSUs in the participant’s account by Emera’s closing common share price on the date DSUs are redeemed.

 

Under the executive and senior management DSU plan, each participant may elect to defer all or a percentage of their annual incentive award in the form of DSUs with the understanding, for participants who are subject to executive share ownership guidelines, a minimum of 50 per cent of the value of their actual annual incentive award (25 per cent in the first year of the program) will be payable in DSUs until the applicable guidelines are met.

 

When incentive awards are determined, the amount elected is converted to DSUs, which have a value equal to the market price of an Emera common share. When a dividend is paid on Emera’s common shares, each participant’s DSU account is allocated additional DSUs equal in value to the dividends paid on an equivalent number of Emera common shares. Following termination of employment or retirement, and by December 15 of the calendar year after termination or retirement, the value of the DSUs credited to the participant’s account is calculated by multiplying the number of DSUs in the participant’s account by the average of Emera’s stock closing price for the fifty trading days prior to a given calculation date. Payments are usually made in cash. At the sole discretion of the Management Resources and Compensation Committee (“MRCC”), payments may be made in the form of actual shares.

 

EMERA 2020 ANNUAL REPORT 151


 

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

In addition, special DSU awards may be made from time to time by the MRCC to selected executives and senior management to recognize singular achievements or by achieving certain corporate objectives.

 

A summary of the activity related to employee and director DSUs for the year ended December 31, 2020 is presented in the following table:

 

    Employee
DSU
    Weighted
Average Grant
Date Fair Value
    Director
DSU
    Weighted
Average Grant
Date Fair Value
 
Outstanding as at December 31, 2019     704,597     $ 34.69       531,454     $ 39.96  
Granted including DRIP     84,790       47.74       93,008       51.65  
Exercised     (127,389 )     30.50       (33,338 )     41.89  
Outstanding and exercisable as at December 31, 2020     661,998     $ 37.17       591,124     $ 41.69  

 

Compensation cost recognized for employee and director DSU’s for the year ended December 31, 2020 was $2 million (2019 – $24 million). Tax benefits related to this compensation cost for share units realized for the year ended December 31, 2020 were $1 million (2019 – $7 million). The aggregate intrinsic value of the outstanding shares for the year ended December 31, 2020 for employees was $36 million (2019 – $40 million). The aggregate intrinsic value of the outstanding shares for the year ended December 31, 2020 for directors was $32 million (2019 – $30 million). Cash payments made during the year ended December 31, 2020 associated with the DSU plan was $11 million (2019 – $22 million).

 

Performance Share Unit Plan 

Under the PSU plan, certain executive and senior employees are eligible for long-term incentives payable through the PSU plan. PSUs are granted annually for three-year overlapping performance cycles, resulting in a cash payment. PSUs are granted based on the average of Emera’s stock closing price for the fifty trading days prior to the effective grant date. Dividend equivalents are awarded and paid in the form of additional PSUs. The PSU value varies according to the Emera common share market price and corporate performance.

 

PSUs vest at the end of the three-year cycle and the payouts will be calculated and approved by the MRCC early in the following year. The value of the payout considers actual service over the performance cycle and may be pro-rated in certain departure scenarios.

 

A summary of the activity related to employee PSUs for the year ended December 31, 2020 is presented in the following table:

 

    Employee
PSU
    Weighted
Average Grant
Date Fair Value
    Aggregate
Intrinsic Value
 
Outstanding as at December 31, 2019     1,381,100     $ 45.37     $ 88  
Granted including DRIP     271,185       53.14          
Exercised     (445,066 )     45.41          
Forfeited     (80,690 )     46.25          
Outstanding as at December 31, 2020     1,126,529     $ 47.16     $ 68  

 

Compensation cost recognized for the PSU plan for the year ended December 31, 2020 was $27 million (2019 – $34 million). Tax benefits related to this compensation cost for share units realized for the year ended December 31, 2020 were $7 million (2019 – $9 million). Cash payments made during the year ended December 31, 2020 associated with the PSU plan was $29 million (2019 – $7 million).

 

Restricted Share Unit Plan 

In 2020, Emera introduced an RSU plan, where certain executive and senior employees are eligible for long-term incentives payable through the RSU plan. RSUs are granted annually for three-year overlapping performance cycles, resulting in a cash payment. RSUs are granted based on the average of Emera’s stock closing price for the fifty trading days prior to the effective grant date. Dividend equivalents are awarded and paid in the form of additional RSUs. The RSU value varies according to the Emera common share market price.

 

152 EMERA 2020 ANNUAL REPORT


 

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

RSUs vest at the end of the three-year cycle and the payouts will be calculated and approved by the MRCC early in the following year. The value of the payout considers actual service over the performance cycle and may be pro-rated in certain departure scenarios.

 

A summary of the activity related to employee RSUs for the year ended December 31, 2020 is presented in the following table:

 

    Employee
RSU
    Weighted
Average Grant
Date Fair Value
    Aggregate
Intrinsic Value
 
Outstanding as at December 31, 2019       $     $  
Granted including DRIP     171,908       54.62          
Forfeited     (5,633 )     54.62          
Outstanding as at December 31, 2020     166,275     $ 54.62     $ 10  

 

Compensation cost recognized for the RSU plan for the year ended December 31, 2020 was $4 million (2019 – nil). Tax benefits related to this compensation cost for share units realized for the year ended December 31, 2020 were $1 million (2019 – nil). Cash payments made during the year ended December 31, 2020 associated with the RSU plan was nil (2019 – nil).

 

32. VARIABLE INTEREST ENTITIES

 

Emera holds a variable interest in NSPML, a VIE for which it was determined that Emera is not the primary beneficiary since it does not have the controlling financial interest of NSPML. When the critical milestones were achieved, Nalcor Energy was deemed the primary beneficiary of the asset for financial reporting purposes as it has authority over the majority of the direct activities that are expected to most significantly impact the economic performance of the Maritime Link. Thus, Emera began recording the Maritime Link as an equity investment.

 

BLPC has established a Self-Insurance Fund (“SIF”), primarily for the purpose of building a fund to cover risk against damage and consequential loss to certain generating, transmission and distribution systems. ECI holds a variable interest in the SIF for which it was determined that ECI was the primary beneficiary and, accordingly, the SIF must be consolidated by ECI. In its determination that ECI controls the SIF, management considered that, in substance, the activities of the SIF are being conducted on behalf of ECI’s subsidiary BLPC and BLPC, alone, obtains the benefits from the SIF’s operations. Additionally, because ECI, through BLPC, has rights to all the benefits of the SIF, it is also exposed to the risks related to the activities of the SIF. Any withdrawal of SIF fund assets by the Company would be subject to existing regulations. Emera’s consolidated VIE in the SIF is recorded as “Other long-term assets”, “Restricted cash” and “Regulatory liabilities” on the Consolidated Balance Sheets. Amounts included in restricted cash represent the cash portion of funds required to be set aside for the BLPC SIF.

 

The Company has identified certain long-term purchase power agreements that meet the definition of variable interests as the Company has to purchase all or a majority of the electricity generation at a fixed price. However, it was determined that the Company was not the primary beneficiary since it lacked the power to direct the activities of the entity, including the ability to operate the generating facilities and make management decisions.

 

The following table provides information about Emera’s portion of material unconsolidated VIEs:

 

As at   December 31, 2020     December 31, 2019  
millions of Canadian dollars     Total Assets      

Maximum

Exposure to

Loss

      Total Assets      

Maximum

Exposure to

Loss

 
Unconsolidated VIEs in which Emera has variable interests                                
NSPML (equity accounted)   $ 547     $ 16     $ 554     $ 23  

 

EMERA 2020 ANNUAL REPORT 153


 

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

33. COMPARATIVE INFORMATION

 

These financial statements contain certain reclassifications of prior period amounts to be consistent with the current period presentation, with no effect on net income.

 

34. SUBSEQUENT EVENTS

 

These financial statements and notes reflect the Company’s evaluation of events occurring subsequent to the balance sheet date through February 16, 2021, the date the financial statements were issued.

 

35. SUPPLEMENTAL FINANCIAL INFORMATION

 

On June 16, 2016, Emera US Finance LP, (in such capacity, the “Issuer”), issued $3.25 billion USD senior unsecured notes

 

(“U.S. Notes”). The U.S. Notes are fully and unconditionally guaranteed, on a joint and several basis, by Emera (in such capacity, the “Parent Company”) and Emera US Holdings Inc. (in such capacity, the “Guarantor Subsidiaries”). Emera owns, directly or indirectly, all of the limited and general partnership interests in Emera US Finance LP.

 

The following condensed consolidated financial statements present the results of operations, financial position and cash flows of the Parent Company, Subsidiary Issuer, Guarantor Subsidiaries and all other Non-guarantor Subsidiaries independently and on a consolidated basis.

 

Our guarantors were not determined using geographic, service line or other similar criteria, and as a result, the “Parent”, “Subsidiary Issuer”, “Guarantor Subsidiaries” and “Non-guarantor Subsidiaries” columns each include portions of our domestic and international operations. Accordingly, this basis of presentation is not intended to present our financial condition, results of operations or cash flows for any purpose other than to comply with the specific requirements for guarantor reporting.

 

154 EMERA 2020 ANNUAL REPORT


 

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

Emera Incorporated

 

CONDENSED CONSOLIDATED STATEMENTS OF INCOME

 

millions of Canadian dollars   Parent     Subsidiary
Issuer
    Guarantor
Subsidiaries
    Non-guarantor
Subsidiaries
    Eliminations     Consolidated  
For the year ended December 31, 2020
Operating revenues   $ (1 )   $     $ 3,456     $ 2,070     $ (19 )   $ 5,506  
Operating expenses     51             2,640       1,688       (20 )     4,359  
Income (loss) from equity investments and subsidiaries     1,049             1       147       (1,048 )     149  
Other income (expenses), net     20             687       1             708  
Interest expense, net (1)     48       (37 )     448       220             679  
Income (loss) before provision for income taxes     969       37       1,056       310       (1,047 )     1,325  
Income tax expense (recovery)     (14 )     (1 )     348       7       1       341  
Net income (loss)     983       38       708       303       (1,048 )     984  
Non-controlling interest in subsidiaries                             1       1  
Preferred stock dividends     45                   1       (1 )     45  
Net income (loss) attributable to common shareholders   $ 938     $ 38     $ 708     $ 302     $ (1,048 )   $ 938  
Comprehensive income (loss) of Emera Incorporated   $ 809     $ 35     $ 575     $ 257     $ (867 )   $ 809  
 
For the year ended December 31, 2019
Operating revenues   $     $     $ 4,125     $ 2,029     $ (43 )   $ 6,111  
Operating expenses     31             3,084       1,695       (42 )     4,768  
Income (loss) from equity investments and subsidiaries     753             2       151       (752 )     154  
Other income (expenses), net     21             22       (11 )     (20 )     12  
Interest expense, net (1)     75       (40 )     481       222             738  
Income (loss) before provision for income taxes     668       40       584       252       (773 )     771  
Income tax expense (recovery)     (40 )     11       60       30             61  
Net income (loss)     708       29       524       222       (773 )     710  
Non-controlling interest in subsidiaries                             2       2  
Preferred stock dividends     45             19       3       (22 )     45  
Net income (loss) attributable to common shareholders   $ 663     $ 29     $ 505     $ 219     $ (753 )   $ 663  
Comprehensive income (loss) of Emera Incorporated   $ 465     $ 14     $ 102     $ 205     $ (321 )   $ 465  
(1) Interest expense is net of interest revenue.

 

EMERA 2020 ANNUAL REPORT 155


 

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

Emera Incorporated 

CONDENSED CONSOLIDATED BALANCE SHEETS

 

millions of Canadian dollars   Parent     Subsidiary
Issuer
    Guarantor
Subsidiaries
    Non-guarantor
Subsidiaries
    Eliminations     Consolidated  
As at December 31, 2020
Assets
Current assets   $ 121     $ 10     $ 1,216     $ 1,010     $ (179 )   $ 2,178  
Property, plant and equipment     21             14,356       5,164       (6 )     19,535  
Other assets
Regulatory assets                 520       899             1,419  
Goodwill     3             5,648       69             5,720  
Other long-term assets     12,522       4,591       130       3,254       (18,115 )     2,382  
Total other assets     12,525       4,591       6,298       4,222       (18,115 )     9,521  
Total assets   $ 12,667     $ 4,601     $ 21,870     $ 10,396     $ (18,300 )   $ 31,234  
                                                 
Liabilities and Equity
Current liabilities   $ 554     $ 2,024     $ 4,121     $ 723     $ (2,547 )   $ 4,875  
Long-term liabilities
Long-term debt     2,210       2,513       4,026       3,590             12,339  
Deferred income taxes           2       852       761       14       1,629  
Regulatory liabilities                 1,747       85             1,832  
Other long-term liabilities     700             4,510       1,666       (5,555 )     1,321  
Total long-term liabilities     2,910       2,515       11,135       6,102       (5,541 )     17,121  
Total Emera Incorporated equity     9,203       62       6,614       3,550       (10,225 )     9,204  
Non-controlling interest in subsidiaries                       21       13       34  
Total equity     9,203       62       6,614       3,571       (10,212 )     9,238  
Total liabilities and equity   $ 12,667     $ 4,601     $ 21,870     $ 10,396     $ (18,300 )   $ 31,234  
                                                 
As at December 31, 2019
Assets
Current assets   $ 96     $ 27     $ 1,486     $ 1,171     $ (294 )   $ 2,486  
Property, plant and equipment     23             13,099       5,040       5       18,167  
Other assets
Regulatory assets                 519       912             1,431  
Goodwill     3             5,762       70             5,835  
Other long-term assets     11,994       3,856       1,739       3,289       (16,955 )     3,923  
Total other assets     11,997       3,856       8,020       4,271       (16,955 )     11,189  
Total assets   $ 12,116     $ 3,883     $ 22,605     $ 10,482     $ (17,244 )   $ 31,842  
                                                 
Liabilities and Equity
Current liabilities   $ 542     $ 12     $ 3,699     $ 992     $ (1,079 )   $ 4,166  
Long-term liabilities
Long-term debt     2,978       3,534       8,829       4,547       (6,209 )     13,679  
Deferred income taxes           3       515       767             1,285  
Regulatory liabilities                 1,793       93             1,886  
Other long-term liabilities     38             1,697       511       (21 )     2,225  
Total long-term liabilities     3,016       3,537       12,834       5,918       (6,230 )     19,075  
Total Emera Incorporated equity     8,558       334       6,072       3,551       (9,949 )     8,566  
Non-controlling interest in subsidiaries                       21       14       35  
Total equity     8,558       334       6,072       3,572       (9,935 )     8,601  
Total liabilities and equity   $ 12,116     $ 3,883     $ 22,605     $ 10,482     $ (17,244 )   $ 31,842  

 

156 EMERA 2020 ANNUAL REPORT


 

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

Emera Incorporated 

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

 

millions of Canadian dollars   Parent     Subsidiary
Issuer
    Guarantor
Subsidiaries
    Non-guarantor
Subsidiaries
    Eliminations     Consolidated  
As at December 31, 2020
Net cash provided by (used in) operating activities   $ 365     $ 36     $ 1,277     $ 486     $ (527 )   $ 1,637  
Investing activities
Additions to property, plant and equipment     (1 )           (2,150 )     (472 )           (2,623 )
Proceeds on disposal of assets                 1,401                   1,401  
Other investing activities     (118 )     265       546       100       (795 )     (2 )
Net cash provided by (used in) investing activities     (119 )     265       (203 )     (372 )     (795 )     (1,224 )
Financing activities
Change in short-term debt, net     (6 )           107       (5 )           96  
Proceeds from long-term debt                 173       429       (174 )     428  
Retirement of long-term debt                 (705 )     (87 )     279       (513 )
Net borrowings (repayments) under committed credit facilities     (82 )           8       (157 )     28       (203 )
Issuance of common and preferred stock     285       (241 )     (3 )     53       191       285  
Dividends paid     (454 )     (66 )     (80 )     (379 )     525       (454 )
Other financing activities     (18 )     (4 )     (494 )     32       473       (11 )
Net cash provided by (used in) financing activities     (275 )     (311 )     (994 )     (114 )     1,322       (372 )
Effect of exchange rate changes on cash, cash equivalents, restricted cash and assets held for sale     18       (8 )     (70 )     (1 )           (61 )
Net increase (decrease) in cash, cash equivalents, restricted cash and assets held for sale     (11 )     (18 )     10       (1 )           (20 )
Cash, cash equivalents and restricted cash, beginning of year     1       19       87       167             274  
Cash, cash equivalents, restricted cash and assets held for sale, end of year   $ (10 )   $ 1     $ 97     $ 166     $     $ 254  

 

EMERA 2020 ANNUAL REPORT 157


 

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

Emera Incorporated 

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (continued)

 

millions of Canadian dollars   Parent     Subsidiary
Issuer
    Guarantor
Subsidiaries
    Non-guarantor
Subsidiaries
    Eliminations     Consolidated  
As at December 31, 2019
Net cash provided by (used in) operating activities   $ 133     $ 33     $ 1,100     $ 279     $ (20 )   $ 1,525  
Investing activities
Additions to property, plant and equipment     (2 )           (1,973 )     (520 )           (2,495 )
Net purchase of investments subject to significant influence                 (3 )                 (3 )
Proceeds on disposal of assets significant influence and held-for-trading common shares                 818       57             875  
Other investing activities     (402 )     595       774       (1 )     (960 )     6  
Net cash provided by (used in) investing activities     (404 )     595       (384 )     (464 )     (960 )     (1,617 )
Financing activities
Change in short-term debt, net     399             (9 )     23             413  
Proceeds from long-term debt                 (6 )     552       520       1,066  
Retirement of long-term debt     (225 )     (664 )     (65 )     (166 )     17       (1,103 )
Net borrowings (repayments) under committed credit facilities     146             (11 )     (225 )     (28 )     (118 )
Issuance of common and preferred stock     203             (620 )     58       562       203  
Dividends paid     (423 )           (19 )     (138 )     157       (423 )
Other financing activities     (1 )           138       87       (248 )     (24 )
Net cash provided by (used in) financing activities     99       (664 )     (592 )     191       980       14  
Effect of exchange rate changes on cash, cash equivalents and restricted cash     147       (3 )     (141 )     (23 )           (20 )
Net increase (decrease) in cash, cash equivalents and restricted cash     (25 )     (39 )     (17 )     (17 )           (98 )
Cash, cash equivalents and restricted cash, beginning of year     20       58       104       190             372  
Cash, cash equivalents and restricted cash, end of year   $ (5 )   $ 19     $ 87     $ 173     $     $ 274  

 

158 EMERA 2020 ANNUAL REPORT


 

EMERA LEADERSHIP AND BOARD

 

As of March 31, 2021

 

EMERA LEADERSHIP

 

Scott Balfour

President and

Chief Executive Officer,

Emera Inc.

Bruce Marchand

Chief Legal and Compliance

Officer,

Emera Inc.

   

Rob Bennett

President and Chief

Executive Officer,

Emera Technologies

 

Greg Blunden

Chief Financial Officer,

Emera Inc.

 

Archie Collins

President and Chief

Operating Officer,

Tampa Electric

 

Peter Gregg

President and Chief

Executive Officer,

Nova Scotia Power

 

Karen Hutt

Executive Vice President,

Business Development

and Strategy,

Emera Inc.

 

Rick Janega

Chief Operating Officer,

Electric Utilities, Canada

and Caribbean,

Emera Inc.

 

Chief Executive Officer,

Emera Newfoundland

and Labrador

Dan Muldoon

Executive Vice President,

Project Development

and Operations Support,

Emera Inc.

 

Michael Roberts

Chief Human Resources

Officer,

Emera Inc.

 

Ryan Shell

President,

New Mexico Gas

 

Judy Steele

President and

Chief Operating Officer,

Emera Energy

 

T.J. Szelistowski

President,

Peoples Gas

 

Nancy Tower

Chief Executive Officer,

Tampa Electric

BOARD OF DIRECTORS

 

Jackie Sheppard

Calgary, Alberta

Chair, Emera Inc.

 

Scott Balfour

Halifax, Nova Scotia

 

James Bertram

Calgary, Alberta

 

Sylvia Chrominska

Stratford, Ontario

 

Henry Demone

Lunenburg, Nova Scotia

 

Kent Harvey

New York, New York

Lynn Loewen

Westmount, Quebec

 

John Ramil

Tampa, Florida

 

Andrea Rosen

Toronto, Ontario

 

Richard Sergel

Boston, Massachusetts

 

Karen Sheriff

Toronto, Ontario

 

Jochen Tilk

Toronto, Ontario



EMERA 2020 ANNUAL REPORT 159


 

SHAREHOLDER INFORMATION

 

For general inquiries about our Company, please contact our corporate office:

 

Emera Inc. 

P.O. Box 910 

Halifax, Nova Scotia  B3J 2W5 

T: 902.450.0507 or 1.888.450.0507

 

Information regarding Company news and initiatives, including our 2020 Annual Report, is also available on our website: www.emera.com

 

TRANSFER AGENT

 

AST Trust Company (Canada)
P.O. Box 2082, Station C
Halifax, NS B3J 3B7 

T: 1.877.982.8762 

F: 902.420.3242 

www.astfinancial.com/ca

 

INVESTOR SERVICES

 

T: 902.428.6060 or 1.800.358.1995 

F: 902.428.6181 

E: investors@emera.com

 

FINANCIAL ANALYSTS, PORTFOLIO MANAGERS AND INSTITUTIONAL INVESTORS

 

Ken McOnie 

Vice President, Investor Relations 

and Treasurer 

T: 902.428.6945 

E: ken.mconie@emera.com

 

Erin Power 

Manager, Investor Relations 

T: 902.428.6760 

E: erin.power@emera.com

 

This Annual Report contains forward-looking information. Actual future results may differ materially. Additional financial and operational information is filed electronically with various securities commissions in Canada through the System for Electronic Document Analysis and Retrieval (SEDAR).

     

SHARE LISTINGS

 

Toronto Stock Exchange (TSX) 

Common shares: EMA 

Preferred shares: EMA.PR.A, EMA.PR.B, EMA.PR.C, EMA.PR.E, EMA.PR.F and EMA.PR.H 

Barbados Stock Exchange (BSE) 

Depositary receipts: EMABDR 

The Bahamas International Securities Exchange (BISX) 

Depositary receipts: EMAB

  

SHARES OUTSTANDING

 

Common shares: 251,430,226 (as of December 31, 2020)

 

DIVIDENDS PAID IN 2020

 

Emera Inc. paid common share dividends at an annualized rate of $2.45 per common share ($0.6125 per quarter) in Q1, Q2 and Q3 and $2.55 ($0.6375 per quarter) in Q4, for an effective annual common share dividend rate of $2.475 per common share.

 

DIVIDEND PAYMENTS IN 2021

 

Subject to approval by the Board of Directors, dividends for Emera Inc. are payable on or about the 15th of February, May, August and November. A first quarter common share dividend of $0.6375, a Series A First Preferred Share dividend of $0.1364, a Series B First Preferred Share dividend of $0.1223, a Series C First Preferred Share dividend of $0.29506, a Series E First Preferred Share dividend of $0.28125, a Series F First Preferred Share dividend of $0.26263 and a Series H First Preferred Share dividend of $0.30625 were declared and paid on February 16, 2021.

     

DIVIDEND REINVESTMENT AND SHARE PURCHASE PLAN

 

Emera’s Dividend Reinvestment and Share Purchase Plan is available to shareholders resident in Canada. The plan provides shareholders with a convenient and economical means of acquiring additional common shares through the reinvestment of dividends up to a five per cent discount. In 2020, the discount was two per cent. Plan participants may also contribute cash payments of up to $5,000 per quarter. Participants of the plan pay no commissions, service charges or brokerage fees for shares purchased under the plan. Please contact Investor Services if you have questions or wish to receive an enrollment form.

 

DIRECT DEPOSIT SERVICE

 

Registered shareholders may have dividends deposited directly to any bank account in Canada. To arrange this service, please contact AST Trust Company (Canada). Beneficial shareholders should contact their financial intermediary.

 

QUARTERLY EARNINGS

 

Quarterly earnings are expected to be announced May, August and November 2021. Year-end results for 2020 were released in February 2021.

 

 

 

(GRAPHIC)  

 

Representation in the TSX Composite, TSX Capped Utilities, TSX60 and select MSCI and FTSE World indexes



160 EMERA 2020 ANNUAL REPORT


 

(GRAPHIC)  

 


 

  (GRAPHIC)  

Exhibit 99.3

 

LOGO    LOGO

Form of Proxy - Emera Inc.

Annual Shareholders Meeting of May 20, 2021

Appointment of Proxyholder

I/We, being holder(s) of Emera Inc. (the “Company”) common shares, hereby appoint: M. Jacqueline Sheppard, or failing her, Scott C. Balfour, or failing him, Stephen D. Aftanas, OR

                                                                                                                                                                                                                     

[Print the name of the person you are appointing if this person is someone other than the individuals listed above.]

as proxy of the undersigned, to participate, act and vote on behalf of the undersigned in accordance with the below direction (or if no directions have been given, as the proxy sees fit) on all of the following matters and any other matter that may properly come before the Annual Meeting of Shareholders of the Company to be held at 11:00 a.m. Atlantic time on Thursday, May 20, 2021, at Emera Place, 5151 Terminal Road, Halifax, Nova Scotia, Canada and virtually at: https://web.lumiagm.com/429761988, using password: emera2021 (case sensitive) (the “Meeting”), and at any and all adjournments or postponements thereof in the same manner, to the same extent and with the same powers as if the undersigned were personally present, with full power of substitution.

Management recommends voting FOR Resolutions 1, 2, 3, 4 and 5. Please use a dark black pencil or pen.

 

1.   

Election of Directors

   FOR    WITHHOLD       FOR    WITHHOLD
  

01.  Scott C. Balfour

        

07.  Andrea S. Rosen

     
  

02.  James V. Bertram

        

08.  Richard P. Sergel

     
  

03.  Henry E. Demone

        

09.  M. Jacqueline Sheppard

     
  

04.  Kent M. Harvey

        

10.  Karen H. Sheriff

     
  

05.  B. Lynn Loewen

        

11.  Jochen E. Tilk

     
  

06.  John B. Ramil

              
2.    Appointment of Auditors    FOR    WITHHOLD
  

Appointment of Ernst & Young LLP as auditors

     
3.    Auditors’ Fee    FOR    AGAINST
  

Authorize Directors to establish the auditors’ fee as required pursuant to the Nova Scotia Companies Act

     
4.   

Advisory Vote on Executive Compensation

Consider and approve, on an advisory basis, a resolution on Emera’s approach to executive compensation as disclosed in the Management Information Circular

  

FOR

  

AGAINST

5.   

Senior Management Stock Option Plan Amendment

Consider and approve an increase in the maximum number of common shares reserved for issuance under the Company’s Senior Management Stock Option Plan from 11,700,000 to 14,700,000 common shares

  

FOR

  

AGAINST

I/We authorize you to act in accordance with my/our instructions set out above. I/We hereby revoke any proxy previously given with respect to the Meeting.

If no voting instructions are indicated above, this Proxy will be voted FOR a matter by Management’s appointees or, if you appoint another proxyholder, as that other proxyholder sees fit. On any amendments or variations proposed or any new business properly submitted before the Meeting, I/We authorize you to vote as you see fit.

 

 

                                                                                                
Signature(s)                            Date

Please sign exactly as your name(s) appears on this proxy. Please see reverse for instructions. All proxies must be received by 5:00 p.m. Atlantic Time, Tuesday, May 18, 2021 or if the meeting is adjourned or postponed, by 5:00 p.m. Atlantic time two business days prior to the reconvened meeting date.

Under Canadian Securities Law, you are entitled to receive certain investor documents. Electronic financial statements and MD&A are available at www.Emera.com and at www.SEDAR.com. If you wish copies, please tick the box below or go to the website https://ca.astfinancial.com/financialstatements and input code 1705a.

 

I would like to receive quarterly financial statements and MD&A.

I would like to receive annual financial statements and MD&A.


Form of Proxy - Emera Inc.

Annual Shareholders Meeting of May 20, 2021

                                                                                                          

 

1.

Every shareholder has the right to appoint some other person or company of the shareholder’s choice, who need not be a shareholder of Emera Inc., to participate, act and vote on the shareholder’s behalf at the meeting or any adjournment or postponement thereof. If you wish to appoint a person or company other than the persons whose names are printed herein, please insert the name of your chosen proxyholder in the space provided on the reverse and return your proxy by mail, fax or email. In addition, to enable your chosen proxyholder to participate and vote virtually at the Meeting, YOU MUST contact AST either by calling 1-866-751-6315 (toll-free in North America) or 1-212-235-5754 (outside North America) or by logging onto the AST website at: https://lp.astfinancial.com/control-number-request-en.html, by 5:00 p.m. Atlantic time on May 18, 2021 or if the meeting is adjourned or postponed, by 5:00 p.m. Atlantic time two business days prior to the reconvened meeting date, to request a new Control Number for the meeting. This new Control Number will allow your proxyholder to log in to and vote at the meeting. Without a new Control Number your proxyholder will only be able to log in to the meeting as a guest and will not be able to vote.

 

2.

This proxy confers discretionary authority on the appointee to vote as the appointee sees fit in respect of amendments or variations to matters identified in the notice of meeting or other matters as may properly come before the Meeting or any adjournment or postponement thereof, in each instance to the extent permitted by law, whether or not the amendment or other matter that comes before the meeting is routine and whether or not the amendment or other matter that comes before the meeting is contested.

 

3.

This proxy must be signed by a holder or his or her attorney duly authorized in writing. If you are an individual, please sign exactly as your name appears on this proxy. If the holder is a corporation, a duly authorized officer or attorney of the corporation must sign this proxy.

 

4.

If the securities are registered in the name of an executor, administrator or trustee, please sign exactly as your name appears on this proxy. If the securities are registered in the name of a deceased or other holder, the proxy must be signed by the legal representative with his or her name printed below his or her signature, and evidence of authority to sign on behalf of the deceased or other holder must be attached to this proxy.

 

5.

Some holders may own securities as both a registered and a beneficial holder and will need to vote separately as a registered holder and as a beneficial holder. Beneficial holders may be forwarded either a form of proxy already signed by the intermediary or a voting instruction form to allow them to direct the voting of securities they beneficially own. Beneficial holders should follow instructions for voting conveyed to them by their intermediaries.

 

6.

If a security is held by two or more individuals, any one of them present or represented by proxy at the Meeting may, in the absence of the other or others, vote at the Meeting. However, if one or more of them are present or represented by proxy, they must vote together the number of securities indicated on the proxy.

 

7.

If this proxy is not dated, it will be deemed to bear the date on which it was mailed on behalf of management of the Company to you.

All holders should refer to the Management Information Circular for further information regarding completion and use of this proxy and other information pertaining to the Meeting.

This proxy is solicited by and on behalf of Management of the Company.

Emera offers a number of ways to cast your vote prior to the meeting. By using one of these ways provided for you, you will be considered to have signed and returned this proxy.

 

 

LOGO INTERNET

 

•   Go to www.astvotemyproxy.com

•   Follow the instructions on the screen

•   You will be required to enter the 13-digit control number located on the reverse

•   No need to return this proxy

  

 

LOGO TELEPHONE

 

•   Use any touch-tone telephone, call toll free in Canada and United States 1-888-489-5760

•   Follow the voice instructions

•   When prompted, enter the 13-digit control number located on the reverse

•   No need to return this proxy

  

 

LOGO SMARTPHONE

 

To vote using your smartphone, please scan this QR Code

 

LOGO

 

•   No need to return this proxy

 

 

LOGO MAIL

 

•   Complete the reverse of this form

•   Return your signed proxy in the envelope provided or send to:

    AST Trust Company (Canada)

    P.O. Box 721

    Agincourt, ON M1S 0A1

 

  

 

LOGO FAX

 

•   Complete the reverse of this form Fax your signed proxy to 1-416-368-2502, or toll free in Canada and United States to 1-866-781-3111

  

 

LOGO EMAIL

 

•   Complete the reverse of this form

•   Scan your signed proxy and email it to proxyvote@astfinancial.com.

All proxies must be received by 5:00 p.m. Atlantic time, Tuesday, May 18, 2021 or if the meeting is adjourned or postponed, by 5:00 p.m. Atlantic time two business days prior to the reconvened meeting date.

Exhibit 99.4

 

LOGO    LOGO

Voting Instruction Form (“VIF”) - Emera Inc.

Annual Shareholders’ Meeting of May 20, 2021

Appointee

I/We, being holder(s) of Emera Inc. (the “Company”) common shares, hereby appoint: M. Jacqueline Sheppard, or failing her, Scott C. Balfour, or failing him, Stephen D. Aftanas, OR

                                                                                                                                                                                      

[To participate in the meeting and vote or to appoint someone to participate and vote on your behalf, print the name of the attendee here.]

as proxy of the undersigned, to participate, act and vote on behalf of the undersigned in accordance with the below direction (or if no directions have been given, as the proxy sees fit) on all of the following matters and any other matter that may properly come before the Annual Meeting of Shareholders of the Company to be held at 11:00 a.m. Atlantic time on Thursday, May 20, 2021, at Emera Place, 5151 Terminal Road., Halifax, Nova Scotia and virtually at: https://web.lumiagm.com/429761988, using password: emera2021 (case sensitive) (the “Meeting”), and at any and all adjournments or postponements thereof in the same manner, to the same extent and with the same powers as if the undersigned were personally present, with full power of substitution.

Management recommends voting FOR Resolutions 1, 2, 3, 4 and 5. Please use a dark black pencil or pen.

 

1.   

Election of Directors

   FOR    WITHHOLD       FOR    WITHHOLD
  

01.  Scott C. Balfour

        

07.  Andrea S. Rosen

     
  

02.  James V. Bertram

        

08.  Richard P. Sergel

     
  

03.  Henry E. Demone

        

09.  M. Jacqueline Sheppard

     
  

04.  Kent M. Harvey

        

10.  Karen H. Sheriff

     
  

05.  B. Lynn Loewen

        

11.  Jochen E. Tilk

     
  

06.  John B. Ramil

              
2.    Appointment of Auditors    FOR    WITHHOLD
  

Appointment of Ernst & Young LLP as auditors

     
3.    Auditors’ Fee    FOR    AGAINST
  

Authorize Directors to establish the auditors’ fee as required pursuant to the Nova Scotia Companies Act

     
4.   

Advisory Vote on Executive Compensation

Consider and approve, on an advisory basis, a resolution on Emera’s approach to executive compensation as disclosed in the Management Information Circular

  

FOR

  

AGAINST

5.   

Senior Management Stock Option Plan Amendment

Consider and approve an increase in the maximum number of common shares reserved for issuance under the Company’s Senior Management Stock Option Plan from 11,700,000 to 14,700,000 common shares

  

FOR

  

AGAINST

I/We authorize you to act in accordance with my/our instructions set out above. I/We hereby revoke any proxy previously given with respect to the Meeting.

If no voting instructions are indicated above, this VIF will be voted FOR a matter by Management’s appointees or, if you appoint another person, as such other person sees fit. On any amendments or variations proposed or any new business properly submitted before the Meeting, I/We authorize you to vote as you see fit.

 

 

                                                                                                
Signature(s)                            Date

Please sign exactly as your name(s) appears on this VIF. Please see reverse for instructions. All VIFs must be received by 5:00 p.m. Atlantic time, Tuesday, May 18, 2021 or if the meeting is adjourned or postponed, by 5:00 p.m. Atlantic time two business days prior to the reconvened meeting date.

Under Canadian Securities Law, you are entitled to receive certain investor documents. Electronic financial statements and MD&A are available at www.Emera.com and at www.SEDAR.com. If you wish copies, please tick the box below or go to the website https://ca.astfinancial.com/financialstatements and input code 1705a.

 

I would like to receive quarterly financial statements and MD&A

I would like to receive annual financial statements and MD&A


Voting Instruction Form (“VIF”) - Emera Inc.

Annual Shareholders Meeting of May 20, 2021

                                                                                                          

 

1.

We are sending to you the enclosed proxy-related materials that relate to a meeting of holders of Emera Inc.’s common shares. Unless you, as an appointee, or an alternate appointee participate(s) in the Meeting and vote(s) in person or virtually, your securities can be voted only by management, as appointee of the registered holder, in accordance with your instructions.

 

2.

Every shareholder has the right to appoint some other person or company of the shareholder’s choice, who need not be a shareholder of Emera Inc., to participate and act on the shareholder’s behalf at the meeting or any adjournment or postponement thereof. If you wish to appoint a person or company other than the persons whose names are printed herein, please insert the name of your chosen proxyholder in the space provided on the reverse and return your proxy by mail, fax or email. In addition, to enable your chosen proxyholder to participate and vote virtually at the Meeting YOU MUST contact AST either by calling 1-866-751-6315 (toll-free in North America) or 1-212-235-5754 (outside North America) or logging onto the AST website at: https://lp.astfinancial.com/control-number-request-en.html, by 5:00 p.m. Atlantic time on May 18, 2021 or if the meeting is adjourned or postponed, by 5:00 p.m. Atlantic time two business days prior to the reconvened meeting date, to request a new Control Number for the meeting. This new Control Number will allow your proxyholder to log in to and vote at the meeting. Without a new Control Number your proxyholder will only be able to log in to the meeting as a guest and will not be able to vote. Unless prohibited by law, the person whose name is written in the space provided will have full authority to present matters to the Meeting and vote on all matters that are presented at the Meeting, even if those matters are not set out in this form or the Management Information Circular. Consult a legal advisor if you wish to modify the authority of that person in any way. If you require help, please contact the Registered Representative who services your account.

 

3.

This VIF confers discretionary authority on the appointee to vote as the appointee sees fit in respect of amendments or variations to matters identified in the notice of meeting or other matters as may properly come before the Meeting or any adjournment or postponement thereof, in each instance to the extent permitted by law, whether or not the amendment or other matter that comes before the meeting is routine and whether or not the amendment or other matter that comes before the meeting is contested.

 

4.

We are prohibited from voting these securities on any of the matters to be acted upon at the Meeting without your specific voting instructions. In order for these securities to be voted at the Meeting, it will be necessary for us to have your specific voting instructions. Please complete and return the information requested in this VIF to provide your voting instructions to us promptly.

 

5.

This VIF should be signed by you in the exact manner as your name appears on the VIF. If these voting instructions are given on behalf of a body corporate, set out the full legal name of the body corporate, the name and position of the person giving voting instructions on behalf of the body corporate, and the address for service of the body corporate.

 

6.

If this VIF is not dated it will be deemed to bear the date on which it is mailed by management to you.

 

7.

When properly signed and delivered, securities represented by this VIF will be voted as directed by you, however, if such a direction is not made in respect of any matter, the VIF will direct the voting of the securities to be made as recommended in the documentation provided by Management for the Meeting.

 

8.

Your voting instructions will be recorded on receipt of the VIF.

 

9.

By providing voting instructions as requested, you are acknowledging that you are the beneficial owner of, and are entitled to instruct us with respect to the voting of, these securities.

 

10.

If you have any questions regarding the enclosed documents, please contact the Registered Representative who services your account.

 

11.

This VIF should be read in conjunction with the Management Information Circular and other proxy materials provided by Management.

All holders should refer to the Management Information Circular for further information regarding completion and use of this VIF and other information pertaining to the Meeting.

Emera offers a number of ways to cast your vote prior to the meeting.

 

 

LOGO INTERNET

•   Go to www.astvotemyproxy.com

•   Follow the instructions on the screen

•   You will be required to enter the 13-digit control number located on the reverse

•   No need to return this VIF

  

 

LOGO TELEPHONE

•   Use any touch-tone telephone, call toll free in Canada and United States 1-888-489-5760

•   Follow the voice instructions

•   When prompted, enter the 13-digit control number located on the reverse

•   No need to return this VIF

  

 

LOGO SMARTPHONE

To vote using your smartphone, please scan this QR Code. There is no need to return this VIF

 

LOGO

 

 

 

LOGO MAIL

•   Complete the reverse of this form

•   Return your signed VIF in the envelope provided or send to:

    AST Trust Company (Canada)

    P.O. Box 721

    Agincourt, ON M1S 0A1

 

  

 

LOGO FAX

•   Complete the reverse of this form Fax your signed VIF to 1-416-368-2502, or toll free in Canada and United States to 1-866-781-3111

  

 

LOGO EMAIL

•   Complete the reverse of this form

•   Scan your signed VIF and email it to proxyvote@astfinancial.com.

All VIFs must be received by 5:00 p.m. Atlantic time, Tuesday, May 18, 2021 or if the meeting is adjourned or postponed,

by 5:00 p.m. Atlantic time two business days prior to the reconvened meeting date.

Exhibit 99.5

 

LOGO

ANNUAL SHAREHOLDERS’ MEETING OF

EMERA INCORPORATED

NOTICE TO REGISTERED SHAREHOLDERS

REGARDING ACCESS TO EMERA’S MANAGEMENT INFORMATION CIRCULAR

and ANNUAL REPORT

 

 

  MEETING DATE and LOCATION

 

  Date:              Thursday, May 20, 2021

 

  Time:              11:00 a.m. Atlantic time

 

  Place:             Emera Place

                          Halifax, Nova Scotia, Canada

  Live audio webcast: https://web.lumiagm.com/429761988

  Meeting password: emera2021 (case sensitive)

 

 

 

Q    WHY AM I RECEIVING THIS NOTICE?
A         

As permitted by Canadian securities regulators, Emera Incorporated (“Company”) is providing you with access to our management information circular (“Information Circular”) for the annual shareholders meeting (“Meeting”) as well as the 2020 Annual Report (together, the “Meeting Materials”), electronically, instead of mailing paper copies. This notice provides you with information on how to view the Meeting Materials online and / or request paper copies. Accompanying this notice is the proxy form that you will need to vote.

Q   

WHERE CAN I ACCESS THE MEETING MATERIALS ON-LINE?

A   

The Meeting Materials can be viewed online at www.meetingdocuments.com/astca/ema as of Thursday, April 8, 2021 for a period of one year following the Meeting, or at www.SEDAR.com.

Q   

HOW CAN I OBTAIN A PAPER COPY OF THE MEETING MATERIALS?

A   

At any time prior to the date of the Meeting, you can request a paper copy of the Meeting Materials free of charge by calling the phone number, sending an email or accessing the website below:

 

 Phone number: Toll free 1-888-433-6443 (or 1-416-682-3801 for shareholders outside of Canada and the United States)

 Email address: fulfilment@astfinancial.com

 Website: www.meetingdocuments.com/astca/ema

 

Paper copies requested before the date of the Meeting will be sent to you within three business days of receiving your request. Therefore, to receive the Meeting Materials prior to the proxy deadline for the Meeting described below, you should make your request before 11:00 a.m. Atlantic time on Wednesday, May 5, 2021. To receive the Meeting Materials prior to the Meeting you should make your request before 11:00 a.m. Atlantic time on Friday, May 7, 2021.

 

Requests for paper copies of the Meeting Materials can be made until one year following the Meeting.

Q   

WHAT MATTERS ARE BEING RECEIVED OR VOTED ON AT THE MEETING?


LOGO

 

A      

  

Shareholders are being asked to vote on the following items of business:

 

   
MEETING BUSINESS ITEM    INFORMATION CIRCULAR REFERENCE

1.  Election of the Board of Directors – elect directors of the Company for the ensuing year.

   See the section entitled “Business of the Meeting – Election of the Board of Directors” in the Information Circular for more information.

2.  Appointment of Auditors – appoint Ernst & Young LLP as auditors for the ensuing year.

   See the section entitled “Business of the Meeting – Appointment of Auditors” in the Information Circular for more information.

3.  Authorize Remuneration of Auditors – authorize the directors to fix the remuneration of the Auditors.

   See the section entitled “Business of the Meeting – Auditors’ Fee” in the Information Circular for more information.

4.  Say on Pay – an advisory resolution on the Company’s approach to executive compensation.

   See the section entitled “Business of the Meeting – Advisory Vote on Executive Compensation” in the Information Circular for more information.

5.  Senior Management Stock Option Plan Amendment – increase the maximum number of common shares reserved for issuance under the Plan.

  

See the section entitled “Business of the

Meeting – Senior Management Stock Option Plan Amendment” in the Information Circular for more information.

 

  

All Shareholders are reminded to review the Information Circular and 2020 Annual Report before voting.

Q         

HOW DO I VOTE MY SHARES?

A   

You may vote by Internet, telephone, posted mail, delivered mail, e-mail, fax or via live webcast. Details of the methods of voting can be found on your accompanying proxy form. You will need your control number contained in the proxy form in order to vote by telephone, by Internet or via the live webcast.

 

To be valid, proxy forms or voting instructions must be received by Emera’s Corporate Secretary, c/o AST Trust Company (Canada) at P.O. Box 721, Agincourt, ON M1S 0A1 by no later than 5:00 p.m. Atlantic time on Tuesday, May 18, 2021 or, if the Meeting is adjourned or postponed, by 5:00 p.m. Atlantic time two business days before the reconvened meeting date. Emera reserves the right to accept late proxies or voting instructions and to waive the proxy deadline, with or without notice, but is under no obligation to accept or reject any particular late proxy or voting instructions.

 

If you wish to appoint someone else to participate and vote virtually on your behalf, you MUST appoint your chosen proxyholder using your proxy form. IN ADDITION, in order for your chosen proxyholder to participate and vote virtually at the Meeting, you must contact AST by 5:00 p.m. Atlantic time on Tuesday, May 18, 2021 to request a new Control Number for the Meeting. In order to request a new Control Number, you may contact AST either by telephone at 1-866-751-6315 (toll-free in North America) or 1-212-235-5754 (outside North America) or by going to AST’s website at: https://lp.astfinancial.com/control-number-request-en.html and completing an electronic form. This form once completed and submitted online will generate a message to AST to send the new Control Number to the designated proxyholder. This new Control Number will allow your chosen proxyholder to log in to and vote at the Meeting. Without a new Control Number your proxyholder will only be able to log in to the Meeting as a guest and will not be able to vote.

Q   

WHO CAN I CONTACT IF I HAVE QUESTIONS ABOUT NOTICE & ACCESS?

A   

Shareholders with questions about notice and access can call toll free at 1-888-433-6443 or 1-416-682-3801 for holders outside of Canada and the United States, respectively, or email fulfilment@astfinancial.com.

 

2

Exhibit 99.6

 

LOGO

ANNUAL SHAREHOLDERS’ MEETING OF

EMERA INCORPORATED

NOTICE TO NON-REGISTERED SHAREHOLDERS

REGARDING ACCESS TO EMERA’S MANAGEMENT INFORMATION CIRCULAR

and ANNUAL REPORT

 

 

  MEETING DATE and LOCATION

 

  Date:              Thursday, May 20, 2021

 

  Time:             11:00 a.m. Atlantic time

 

  Place:             Emera Place

                           Halifax, Nova Scotia, Canada

  Live audio webcast: https://web.lumiagm.com/429761988

  Meeting password: emera2021 (case sensitive)

 

 

 

Q          WHY AM I RECEIVING THIS NOTICE?
A   

As permitted by Canadian securities regulators, Emera Incorporated (“Company”) is providing you with access to our management information circular (“Information Circular”) for the annual shareholders meeting (“Meeting”) as well as the 2020 Annual Report (together, the “Meeting Materials”), electronically, instead of mailing paper copies. This notice provides you with information on how to view the Meeting Materials online and / or request paper copies. Accompanying this notice is the voting information form that you will need to vote.

Q   

WHERE CAN I ACCESS THE MEETING MATERIALS ON-LINE?

A   

The Meeting Materials can be viewed online at www.meetingdocuments.com/astca/ema as of Thursday, April 8, 2021 for a period of one year following the Meeting, or at www.SEDAR.com.

Q   

HOW CAN I OBTAIN A PAPER COPY OF THE MEETING MATERIALS?

A   

At any time prior to the date of the Meeting, you can request a paper copy of the Meeting Materials free of charge by calling the phone number, sending an email or accessing the website below:

 

 Phone number: Toll free 1-888-433-6443 (or 1-416-682-3801 for shareholders outside of Canada and the United States)

 Email address: fulfilment@astfinancial.com

 Website: www.meetingdocuments.com/astca/ema

 

Paper copies requested before the date of the Meeting will be sent to you within three business days of receiving your request. Therefore, to receive the Meeting Materials prior to the proxy deadline for the Meeting described below, you should make your request before 11:00 a.m. Atlantic time on Wednesday, May 5, 2021. To receive the Meeting Materials prior to the Meeting you should make your request before 11:00 a.m. Atlantic time on Friday, May 7, 2021.

 

Requests for paper copies of the Meeting Materials can be made until one year following the Meeting.

Q   

WHAT MATTERS ARE BEING RECEIVED OR VOTED ON AT THE MEETING?


LOGO

 

A      

  

Shareholders are being asked to vote on the following items of business:

 

   
MEETING BUSINESS ITEM    INFORMATION CIRCULAR REFERENCE

1.  Election of the Board of Directors – elect directors of the Company for the ensuing year.

   See the section entitled “Business of the Meeting – Election of the Board of Directors” in the Information Circular for more information.

2.  Appointment of Auditors – appoint Ernst & Young LLP as auditors for the ensuing year.

   See the section entitled “Business of the Meeting – Appointment of Auditors” in the Information Circular for more information.

3.  Authorize Remuneration of Auditors – authorize the directors to fix the remuneration of the Auditors.

   See the section entitled “Business of the Meeting – Auditors’ Fee” in the Information Circular for more information.

4.  Say on Pay – an advisory resolution on the Company’s approach to executive compensation.

  

See the section entitled “Business of the Meeting

- Advisory Vote on Executive Compensation” in

the Information Circular for more information.

5.  Senior Management Stock Option Plan Amendment– increase the maximum number of common shares reserved for issuance under the Plan.

  

See the section entitled “Business of the

Meeting – Senior Management Stock Option Plan Amendment” in the Information Circular for more information.

 

  

All Shareholders are reminded to review the Information Circular and 2020 Annual Report before voting.

Q         

HOW DO I VOTE MY SHARES?

A   

Details of the methods of voting can be found on your accompanying voting instruction form “(VIF”). To the extent specified on your VIF, you may vote by Internet, telephone, posted mail, delivered mail, e-mail, fax or via live webcast. You will need your control number contained in the VIF in order to vote by telephone, by Internet or via the live webcast.

 

To be valid, VIF’s or voting instructions must be received by Emera’s Corporate Secretary, c/o AST Trust Company (Canada) at P.O. Box 721, Agincourt, ON M1S 0A1 by no later than 5:00 p.m. Atlantic time on Tuesday, May 18, 2021 or, if the Meeting is adjourned or postponed, by 5:00 p.m. Atlantic time two business days before the reconvened meeting date. Emera reserves the right to accept late VIF’s or voting instructions and to waive the proxy deadline, with or without notice, but is under no obligation to accept or reject any particular late VIF or voting instructions.

 

If you wish to participate and vote at the Meeting virtually, or you wish to appoint someone else to participate and vote virtually on your behalf, you MUST appoint yourself or your chosen proxyholder using your VIF. IN ADDITION, in order for your chosen proxyholder to participate and vote virtually at the Meeting, you must contact AST by 5:00 p.m. Atlantic time on Tuesday, May 18, 2021 to request a new Control Number for the Meeting. In order to request a new Control Number, you may contact AST either by telephone at 1-866-751-6315 (toll-free in North America) or 1-212-235-5754 (outside North America), or by going to AST’s website at: https://lp.astfinancial.com/control-number-request-en.html and completing an electronic form. This form once completed and submitted online will generate a message to AST to send the new Control Number to the designated proxyholder. This new Control Number will allow you or your chosen proxyholder to log in to and vote at the Meeting. Without a new Control Number you or your proxyholder will only be able to log in to the Meeting as a guest and will not be able to vote.

Q   

WHO CAN I CONTACT IF I HAVE QUESTIONS ABOUT NOTICE & ACCESS?

A   

Shareholders with questions about notice and access can call toll free at 1-888-433-6443 or 1-416-682-3801, for holders outside of Canada and the United States, respectively, or email fulfilment@astfinancial.com.

 

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