0001193125-19-102638.txt : 20190410 0001193125-19-102638.hdr.sgml : 20190410 20190410132015 ACCESSION NUMBER: 0001193125-19-102638 CONFORMED SUBMISSION TYPE: 6-K PUBLIC DOCUMENT COUNT: 75 CONFORMED PERIOD OF REPORT: 20190410 FILED AS OF DATE: 20190410 DATE AS OF CHANGE: 20190410 FILER: COMPANY DATA: COMPANY CONFORMED NAME: EMERA INC CENTRAL INDEX KEY: 0001127248 STANDARD INDUSTRIAL CLASSIFICATION: ELECTRIC SERVICES [4911] IRS NUMBER: 868143132 FISCAL YEAR END: 1231 FILING VALUES: FORM TYPE: 6-K SEC ACT: 1934 Act SEC FILE NUMBER: 000-54516 FILM NUMBER: 19741270 BUSINESS ADDRESS: STREET 1: 1223 LOWER WATER ST., B-6TH FLOOR STREET 2: P.O. BOX 910 CITY: HALIFAX STATE: A5 ZIP: B3J 3S8 BUSINESS PHONE: 902-428-6494 MAIL ADDRESS: STREET 1: 1223 LOWER WATER ST., B-6TH FLOOR STREET 2: P.O. BOX 910 CITY: HALIFAX STATE: A5 ZIP: B3J 3S8 6-K 1 d732548d6k.htm FORM 6-K Form 6-K

 

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, 2019

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 10, 2019     By:              

\s\Stephen Aftanas

      Name: Stephen D. Aftanas
      Title: Corporate Secretary


EXHIBIT INDEX

 

Exhibit No.                

  

Description

99.1

   Emera Notice of Annual Meeting of Common Shareholders Wednesday, May 15, 2019 and 2019 Management Information Circular

99.2

   Emera 2018 Annual Report

99.3

   Emera Form of Proxy relating to Emera’s May 15, 2019 shareholder meeting

99.4

   Voting Instructions Form (VIF) relating to Emera’s May 15, 2019 shareholder meeting

99.5

   Emera Notice and Access Notification to Shareholders

99.6

   Emera Notice and Access Notification to Non-Registered Shareholders
EX-99.1 2 d732548dex991.htm EX-99.1 EX-99.1

Exhibit 99.1

Emera

Incorporated

Notice of Annual Meeting of Common Shareholders and Management Information Circular

Wednesday, May 15, 2019

 

 

LOGO


Dear Fellow Shareholder:

 

We invite you to attend the Annual Meeting of the common Shareholders of Emera Incorporated, which will be held at the Halifax Convention Centre, Argyle Suite, Level 2, 1650 Argyle Street, Halifax, Nova Scotia, on Wednesday, May 15, 2019 at 2:00 p.m. (Atlantic Time).

 

The Board of Directors and the executive team look forward to meeting with you to present our analysis of our 2018 financial results and outline our plans for the future.

 

Please take time to read this document. The Management Information Circular contains important information about the business to be conducted at the Annual Meeting, about the Directors nominated for election, about how we compensate our executive officers and Directors, and about our corporate governance practices. If you cannot attend the Annual Meeting, please use the proxy or voting instruction form provided to you in order to submit your vote prior to the meeting. It is important to us that your shares be counted.

 

Live coverage of the Annual Meeting will be available on our website at www.emera.com/investors. A recording of the meeting will be available on the site for several weeks following the meeting.

 

We hope you can join us.

  

 

Sincerely,
LOGO
Jackie Sheppard
Chair of the Board

Table of Contents

 

Notice of Annual Meeting

     1  

Management Information Circular

     2  

Business of the Meeting

     4  

Director Nominees

     5  

Skills and Experience

     6  

Statement of Corporate Governance Practices

     23  

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

     37  

Statement of Executive Compensation

     40  

Compensation Discussion and Analysis

     45  

Performance Graph

     58  

NEO Summary Compensation Table

     60  

Appendix “A” – Board of Directors Charter

     71  


 

Notice of Annual Meeting

 

Wednesday, May 15, 2019

2:00 p.m. Atlantic Time

  

Halifax Convention

Centre,

1650 Argyle Street

Halifax, Nova Scotia,

Canada

     

Record Date

Close of business

March 20, 2019

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; and

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

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 2:00 p.m. Atlantic Time on Monday, May 13, 2019, or if the meeting is adjourned, at least 48 hours (not including Saturdays, Sundays, or statutory holidays in Nova Scotia) prior to the reconvened meeting.

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

 

Emera Inc. — Management Information Circular 2019            1


 

Management Information Circular

Information as of March 22, 2019

(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 2018 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 or 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 Wednesday, May 15, 2019, 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 Wednesday, March 20, 2019. 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 235,872,307 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, you are a registered Shareholder. If you do not hold shares in your own name, you are a beneficial or non-registered owner. If your shares are listed in an account statement 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.

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.

 

2             Emera Inc. — Management Information Circular 2019


MANAGEMENT INFORMATION CIRCULAR

 

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 Non-Objecting Beneficial Owners, and (ii) executing their proper voting instructions. Please return voting instructions as specified in the voting instruction form or form of proxy.

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.

In order 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 Monday, May 13, 2019, or if the meeting is adjourned, at least 48 hours (not including Saturdays, Sundays or statutory holidays in Nova Scotia) prior to the reconvened meeting. 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 any particular 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 or she sees fit in respect of amendments to matters identified in the Notice, and other matters that may properly come before the Meeting or any adjournment 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; and

 

advisory resolution on the Company’s approach to executive compensation.

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 attend and vote at the Meeting in order for your vote to count.

You may revoke your proxy by providing new voting instructions in a new proxy or voting instructions 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 2:00 p.m. (Atlantic Time) on Monday, May 13, 2019 or if the meeting is adjourned, at least 48 hours (not including Saturdays, Sundays or statutory holidays in Nova Scotia) prior to the reconvened meeting. 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 any postponement or adjournment thereof or with the Chair of the Meeting on the day of the Meeting or 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.

Restrictions 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. Shareholders who are not residents of Canada may not hold, in the aggregate, more than 25 per cent of the outstanding voting shares.

These restrictions may be enforced by limiting non-complying Shareholders’ voting rights (including, in the case of the individual share constraint, by disqualifying or deeming votes to have not been cast by such non-complying Shareholders, and in the case of the non-resident share constraint, by proportionally adjusting the number of shares voted by non-resident Shareholders so that such votes cast equal 25 per cent of all votes cast), dividend rights and transfer rights. Shareholders may be required, at any time, to furnish a statutory declaration to verify the number of shares held and/or residency in order to ensure compliance with these restrictions.

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

 

Emera Inc. — Management Information Circular 2019            3


 

Business of the Meeting

 

1.

Election of the Board of Directors: The 12 nominees proposed for election as Directors at the 2019 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 “For” the 12 nominees unless instructed otherwise by Shareholders in their proxy.

 

2.

Appointment of Auditors: The Audit Committee has reviewed the performance of Ernst & Young LLP, including its independence relating to the audit, and recommends the re-appointment of Ernst & Young LLP as Auditors. Ernst & Young LLP have been Auditors of the Company since its inception in 1998, and before that were Auditors of the Company’s subsidiary, Nova Scotia Power Inc. (“NSPI”), since 1991.

Ms. Sheppard, Mr. Balfour and Mr. Aftanas intend to vote “For” the re-appointment 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, 2017 and December 31, 2018, were as follows:

 

   

Service Fee

 

  

2018 ($)

 

    

2017 ($)

 

 
 

 

 
 

 

Audit Fees(1)

 

  

 

 

 

 

2,540,734

 

 

 

 

  

 

 

 

 

                         1,711,880

 

 

 

 

 

 

 
 

Audit-Related Fees(2)

 

    

 

154,300

 

 

 

    

 

461,269

 

 

 

 

 

 
 

Tax Fees(3)

 

    

 

282,326

 

 

 

    

 

468,051

 

 

 

 

 

 
 

All Other Fees(4)

 

    

 

13,500

 

 

 

    

 

133,000

 

 

 

 

 

 
 

Total

 

    

 

2,990,860

 

 

 

    

 

2,774,201

 

 

 

 

 

 
  (1)

In the first quarter of 2018, Ernst & Young LLP assumed the responsibility as Auditors of Emera’s subsidiary, TECO Energy, Inc. (TECO). Accordingly, the 2018 Audit Fees shown above include the consolidation of such fees for Emera and TECO. For comparison purposes, in 2017 the consolidated Audit Fees were $4,116,064.

  (2)

Audit-Related Fees for Emera relate to accounting and disclosure consultations.

  (3)

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.

  (4)

All Other Fees relate to other consulting fees.

Ms. Sheppard, Mr. Balfour and Mr. Aftanas intend to vote “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.

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:

“BE IT 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 information circular delivered in advance of the 2019 Annual Meeting of Shareholders.”

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 “For” the advisory resolution on executive compensation.

 

4             Emera Inc. — Management Information Circular 2019


MANAGEMENT INFORMATION CIRCULAR

 

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, 2016

 

    

 

45.39

 

 

 

December 31, 2017

 

    

 

46.98

 

 

 

December 31, 2018

 

    

 

43.71

 

 

 

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 Mr. 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.

 

Emera Inc. — Management Information Circular 2019            5


 

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 12 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 2018 Annual Meeting of Shareholders are shown in the two rows below.

 

                       
    

LOGO

 

    

LOGO

 

    

LOGO

 

    

LOGO

 

    

LOGO

 

    

LOGO

 

    

LOGO

 

    

LOGO

 

    

LOGO

 

    

LOGO

 

    

LOGO

 

    

LOGO

 

 

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

     99.36          99.64          98.70          99.21          99.65          99.75          99.77          99.24          99.38          99.03          99.75          99.33    

Percentage of votes cast “Withheld” (%)

     0.64          0.36          1.30          0.79          0.35          0.25          0.23          0.76          0.62          0.97          0.25          0.67    

 

6             Emera Inc. — Management Information Circular 2019


MANAGEMENT INFORMATION CIRCULAR

 

 

 

Scott Balfour

 

Age: 54

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, before that, Chief Financial Officer. Before joining Emera, he served 17 years in a variety of roles, including as President and Chief Financial Officer with the Aecon Group Inc., a Canadian publicly traded construction and infrastructure development company.

Mr. Balfour is a Director of many Emera subsidiaries, including being Chairman of Tampa Electric Company and Nova Scotia Power Inc. He is also a director of Martinrea International Inc. He is past Chair of the Ontario Energy Association.

Mr. Balfour received his Masters 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, as well as his experience growing a business through mergers and acquisitions 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)

     6 of 6            100%         

•  Martinrea International Inc.
(June 2013 to present)

 

 

 

 

  DSUs Awarded and Held

 

 

2018 share-based    

awards ($)    

 

  

 

Total 2018 increase in value    

of all DSUs held ($)    

 

  

 

Market value of total    

DSU holdings ($)    

 

     

236,127 (2)

 

  

191,397    

 

  

2,233,712    

 

 

 

  Securities Held

 

         

    Year    

 

  

Common
shares

 

    

DSUs

 

    

Value of shares
and DSUs ($)

 

   

Status under share ownership

guidelines

 

         
2018

 

2017

    

 

50,627

 

35,759

 

 

 

    

 

51,103

 

43,472

 

 

 

    

 

4,446,618

 

3,722,272

 

 

 

 

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 is on track to meet this requirement within the required time frame.

 

(1)

Mr. Balfour is not a member of any Committee of the Board; however, he did participate in all Emera Committee meetings held in 2018.

(2)

For Mr. Balfour, this amount represents the DSUs received by him in 2018. DSUs he received in 2018 were granted on account of payments under the 2017 Short-Term Incentive Plan (STIP). For information about DSUs received on account of his 2018 STIP payout, please see the Statement of Executive Compensation.

 

 

Emera Inc. — Management Information Circular 2019            7


    

 

 

 

James Bertram

 

Age: 62

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.

Mr. Bertram is Chair of the Board of Keyera Corp., one of Canada’s leading publicly traded midstream oil and gas operators. He was President and Chief Executive Officer of Keyera from its inception in 2003 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 will make 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

    

 

4 of 4    

 

1 of 1    

 

 

 

    

 

100%    

 

100%    

 

 

 

  

●   Keyera Corp. (2003 to
present)

 

●   Methanex Corporation
(October 2018 to present)

 

●   Legacy Oil + Gas Inc. (2009
to 2015)

 

 

 

    Total Compensation

 

Fees earned in 2018 ($)    

 

  

All other compensation ($)    

 

  

Total ($)     

 

     

113,732    

 

  

N/A    

 

  

113,732     

 

 

 

    DSUs Awarded and Held

 

     

2018 share-based    

awards ($)    

 

  

Total 2018 increase in value    

of all DSUs held ($)    

 

  

Market value of total    

DSU holdings ($)    

 

     

113,732    

 

  

106,413    

 

  

106,413    

 

 

 

    Securities Held

 

    Year    

 

  

Common
shares

 

    

DSUs

 

    

Value of shares
and DSUs ($)

 

   

Status under share

ownership guidelines

 

         
2018      Nil        2,434        106,390    

Mr. Bertram owns shares and DSUs valued at 19% of the requirement under the Share Ownership guidelines. He has until July 2023 to meet the guidelines.

 

 

 

8             Emera Inc. — Management Information Circular 2019


MANAGEMENT INFORMATION CIRCULAR

 

 

 

Sylvia Chrominska

 

Age: 67

Toronto, Ontario

Canada

Director Since: 2010

Independent

 

LOGO

 

Skills and Experience

•  CEO/Senior Executive

•  Customer/Stakeholder

•  M&A/Growth Strategy

•  Governance/Other Directorship

•  Financial

•  Compensation and Human Resources

•  Legal and Regulatory

 

 

 

Ms. Chrominska has been a Director since September 2010. She has been a member of the Management Resources and Compensation Committee since November 2010, and became Chair of the Committee in May 2016. She was a member of the Nominating and Corporate Governance Committee from June 2012 to September 2014. She was Chair of the ad hoc Pension Governance Committee from its inception in November 2013 until its termination in May 2014.

Ms. Chrominska is the former Group Head of Global Human Resources and Communications for The Bank of Nova Scotia, where she had global responsibility for human resources, corporate communications, government relations, public policy and corporate social responsibility of the Scotiabank Group. Ms. Chrominska is the former Chair of the Board of Scotiabank Trinidad and Tobago Limited and Scotia Group Jamaica Limited. Ms. Chrominska is also a Director of Wajax Corporation and of the Canada Pension Plan Investment Board.

Ms. Chrominska graduated from the University of Western Ontario with an Honours Degree in Business Administration. She also serves on the Dean’s Advisory Board at the Richard Ivey School of Business and is a member of the Board of Governors of the University of Western Ontario. She received an honorary Doctor of Laws from the University of Western Ontario in 2014.

Ms. Chrominska’s 30-year career in the banking sector has provided her with valuable skills and knowledge in financial and credit matters. In particular, the experience she has gained through her senior executive leadership roles, with responsibilities encompassing a broad spectrum of areas within a complex, global business organization, is a distinct asset.

 

 

    Board/Committee

    Membership

 

  

Attendance    

 

    

Total    

 

    

Public Company Board Membership

During the Last Five Years

 

       

•  Board member

•  Management Resources and Compensation Committee Chair

    

6 of 6    

3 of 3    

 

 

    

100%    

100%    

 

 

  

•  Wajax Corporation
(May 2015 to present)

•  Scotia Group Jamaica Limited
(2009 to March 2016)

•  Scotiabank Trinidad and Tobago Limited (January 2013 to March 2015)

 

 

 

    Total Compensation

 

Fees earned in 2018 ($)    

 

  

All other compensation ($)    

 

  

Total ($)    

 

     

225,500    

 

  

N/A    

 

  

225,500    

 

 

 

    DSUs Awarded and Held

 

     

2018 share-based    

awards ($)    

 

  

Total 2018 increase in value    

of all DSUs held ($)    

 

  

Market value of total    

DSU holdings ($)    

 

     

200,375    

 

  

167,777    

 

  

1,462,029    

 

 

 

    Securities Held

 

    Year    

 

  

Common
shares

 

    

DSUs

 

    

Value of shares
and DSUs ($)

 

   

Status under share ownership

guidelines

 

         
2018

2017

2016

    

2,529

2,529

2,529

 

 

 

    

33,448

27,549

21,985

 

 

 

    

1,572,555

1,413,064

1,112,690

 

 

 

 

Ms. Chrominska owns shares and DSUs valued at 276% of the requirement under the Share Ownership guidelines; therefore, the guidelines are met.

 

 

 

Emera Inc. — Management Information Circular 2019            9


    

 

 

 

Henry Demone

 

Age: 64

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 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 currently sits on the Board of Saputo Inc. 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, 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

     6 of 6        100%     

•  High Liner Foods Inc. (1989 to present)

•  Nominating and

Corporate

Governance

Committee member

     4 of 4        100%     

•  Saputo Inc. (2012 to present)

•  Management

Resources and Compensation

Committee member

 

     3 of 3        100%       

 

 

 

    Total Compensation

 

 

Fees earned in 2018 ($)  

 

  

 

All other compensation ($)  

 

  

Total ($)  

 

 

222,625  

 

  

 

N/A  

 

  

 

222,625  

 

 

 

    DSUs Awarded and Held

 

 

2018 share-based  

awards ($)  

 

  

 

Total 2018 increase in value  

of all DSUs held ($)  

 

  

 

Market value of total  

DSU holdings ($)  

 

 

222,625  

 

  

 

199,955  

 

  

 

854,903  

 

 

 

    Securities Held

 

              

 

Year  

 

  

 

Common  
shares  

 

    

DSUs  

 

    

 

Value of shares  
and DSUs ($)  

 

    

 

Status under share ownership guidelines

 

2018

2017

2016

 

    

 

10,417    

10,508    

10,508    

 

 

 

 

 

    

 

19,558    

13,941    

8,652    

 

 

 

 

 

    

 

1,310,207      
1,148,614      

869,672      

 

 
 

 

 

  

Mr. Demone owns shares and DSUs valued at 230% of the requirement under the Share Ownership guidelines; therefore, the guidelines are met.

 

 

 

 

 

10             Emera Inc. — Management Information Circular 2019


MANAGEMENT INFORMATION CIRCULAR

 

 

 

Kent Harvey

 

Age: 60

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.

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

     6 of 6        100%      None

•  Audit Committee

member

 

    

 

5 of 5  

 

 

 

  

100%  

 

    

 

 

    Total Compensation

 

 

Fees earned in 2018 ($)  

 

  

 

All other compensation ($)  

 

  

 

Total ($)  

 

 

247,290  

 

  

 

N/A  

 

  

 

247,290  

 

 

 

    DSUs Awarded and Held

 

 

2018 share-based  

awards ($)  

 

  

 

Total 2018 increase in value  

of all DSUs held ($)  

 

  

 

Market value of total DSU   holdings ($)  

 

 

125,000  

 

  

 

118,362  

 

  

 

136,794  

 

 

 

    Securities Held

 

             

Year    

 

  

 

Common  
shares  

 

    

DSUs  

 

    

 

Value of shares  

and DSUs ($)  

 

    

 

Status under share ownership

guidelines

 

         

2018    

 

2017    

 

    

 

 

Nil  

 

Nil  

 

 

 

 

 

    

 

 

3,129  

 

392  

 

 

 

 

 

    

 

 

136,768

 

18,432

 

 

 

 

 

  

Mr. Harvey owns DSUs valued at 24% of the requirement under the Share Ownership guidelines. He has until November 2022 to meet the guidelines.

 

 

 

Emera Inc. — Management Information Circular 2019            11


    

 

 

 

Lynn Loewen, FCPA, FCA

 

Age: 57

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 currently President of Minogue Medical Inc. 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 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

     6 of 6        100%      None

•  Audit Committee

member

     5 of 5        100%       

•  Health, Safety and

Environment

Committee member

     3 of 3        100%       

 

 

 

    Total Compensation

 

 

Fees earned in 2018 ($)  

 

  

 

All other compensation ($)  

 

  

 

Total ($)  

 

223,625  

 

  

N/A  

 

  

223,625  

 

 

 

    DSUs Awarded and Held

 

 

2018 share-based  

awards ($)  

 

  

 

Total 2018 increase in value  

of all DSUs held ($)  

 

  

 

Market value of total  

DSU holdings ($)  

 

 

223,625  

 

  

 

195,141  

 

  

 

1,192,949  

 

 

 

    Securities Held

 

              

Year    

 

  

Common  
shares  

 

    

DSUs  

 

    

Value of shares  
and DSUs ($)  

 

    

Status under share ownership

guidelines

 

         

2018    

2017    

2016    

 

    

 

3,999  

3,777  

3,603  

 

 

 

 

 

    

 

27,292  

21,239  

15,440  

 

 

 

 

 

    

 

1,367,730  

1,175,252  

864,362  

 

 

 

 

 

  

Ms. Loewen owns shares and DSUs valued at 240% of the requirement under the Share Ownership guidelines; therefore, the guidelines are met.

 

 

 

12             Emera Inc. — Management Information Circular 2019


MANAGEMENT INFORMATION CIRCULAR

 

 

 

 

Donald Pether

 

Age: 71

Dundas, Ontario

Canada

Director Since: 2008

Independent

LOGO

 

Skills and Experience

•  CEO/Senior Executive

•  Customer/Stakeholder

•  M&A/Growth Strategy

•  Governance/Other Directorship

•  Financial

•  Compensation and Human Resources

•  Legal and Regulatory

 

 

 

Mr. Pether has been a Director since November 2008. He has been a member of the Nominating and Corporate Governance Committee since May 2009, and was appointed Chair of the Committee in April 2012. He became a member of the Health, Safety and Environment Committee in November 2017, and was a member of the Audit Committee from November 2014 to November 2017. He was also a member of the Management Resources and Compensation Committee from May 2009 to September 2014. He was a member of the ad hoc Pension Governance Committee from its inception in November 2013 until its termination in May 2014.

Mr. Pether is the former Chair of the Board and Chief Executive Officer of ArcelorMittal Dofasco Inc., a Canadian steel producer. He is a past-Chair of the Board of the Hamilton Health Sciences Foundation, the McMaster Innovation Park and McMaster University. He currently sits on the Board of the Manning Innovation Awards Foundation, the Board of the National Gallery of Canada Foundation and the Council of Governors for the Art Gallery of Hamilton. He is a Director of Samuel, Son & Co. Ltd. and Schlegel Health Care Inc.

Mr. Pether has a Bachelor of Science in Metallurgical Engineering from the University of Alberta and holds an honorary Doctor of Laws from McMaster University.

Mr. Pether’s experience as a chief executive officer of a steel producer owning assets in the mining and automotive parts industry, and with employees in the US, Mexico and Canada, provides him with valuable business and stakeholder skills. Mr. Pether’s experience throughout his career with employee and labour relations, as well as with innovative manufacturing and maintenance processes, are of significant benefit to the Board.

 

 

Board/Committee

Membership

 

  

Attendance   

 

  

Total

 

    

Public Company Board Membership

During the Last Five Years

 

 

•  Board member

•  Nominating and Corporate Governance Committee Chair

•  Health, Safety and Environment
Committee

 

  

 

6 of 6  

4 of 4  

 

 

 

 

 

3 of 3  

  

 

 

 

 

 

 

 

 

100%

100%

 

 

 

 

 

100%

 

 

 

 

 

 

 

 

 

  

 

•  Primary Energy Recycling Corporation
(April 2010 to December 2014)

 

 

 

Total Compensation

 

 

            Fees earned in 2018 ($)  

 

  

All other compensation ($)  

 

  

Total ($)  

 

227,375  

 

  

 

N/A  

 

  

227,375  

 

 

 

DSUs Awarded and Held

 

 

2018 share-based  

awards ($)  

 

  

Total 2018 increase in value  

of all DSUs held ($)  

 

  

Market value of total  

DSU holdings ($)  

 

 

227,375  

 

  

 

182,546  

 

  

 

2,107,364  

 

 

 

Securities Held

 

Year  

 

    

Common  
shares  

 

    

DSUs  

 

    

 

Value of shares  
and DSUs ($)  

 

    

Status under share ownership

guidelines

 

 

 

 

2018    

2017    

2016    

 

 

 

 

  

 

 

 

1,338  

1,265  

1,208  

 

 

 

 

  

 

 

 

48,212  

40,971  

34,032  

 

 

 

 

  

 

 

 

2,165,831  

1,984,247  

1,599,544  

 

 

 

 

  

 

Mr. Pether owns DSUs valued at 380% of the requirement under the Share Ownership guidelines; therefore, the guidelines are met.

 

 

 

Emera Inc. — Management Information Circular 2019            13


    

 

 

 

 

 

John Ramil

 

Age: 63

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 has been a significant leader in the Tampa Bay community. He is Chair of the Boards of GuideWell Mutual Holding Corporation and Blue Cross Blue Shield of Florida.

He serves on the Board of Directors of the Moffitt Cancer Center Institute.

He is a member of the Florida Council of 100 and 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.

Mr. Ramil received his Bachelor of Science, Master of Science and Honorary Doctorate degrees in Engineering from the University of South Florida (USF). In 1999, he was named USF’s Distinguished Alumnus. He is the longest-serving member of the USF Board of Trustees and served 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 across all of its businesses.

 

 

Board/Committee

Membership

 

  

Attendance   

 

  

Total

 

    

Public Company Board Membership

During the Last Five Years

 

 

•  Board member

•  Health, Safety and Environment
Committee member

 

 

  

 

6 of 6  

3 of 3  

  

 

 

 

100%

100%

 

 

 

  

 

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

 

 

Total Compensation

 

 

            Fees earned in 2018 ($)  

 

  

All other compensation ($)  

 

  

Total ($)  

 

246,472   

 

  

 

N/A  

 

  

246,472   

 

 

 

DSUs Awarded and Held

 

 

2018 share-based  

awards ($)  

 

  

Total 2018 increase in value  

of all DSUs held ($)  

 

  

Market value of total  

DSU holdings ($)  

 

 

246,472   

 

  

 

228,271   

 

  

 

555,252   

 

 

 

Securities Held

 

Year  

 

    

Common  
shares  

 

    

DSUs  

 

    

 

Value of shares  
and DSUs ($)  

 

    

Status under share ownership

guidelines

 

 

 

 

2018    

2017    

 

 

 

  

 

 

 

Nil  

Nil  

 

 

 

  

 

 

 

12,703  

6,960  

 

 

 

  

 

 

 

555,248  

326,981  

 

 

 

  

 

Mr. Ramil owns shares and DSUs valued at 97% of the requirement under the Share Ownership guidelines. He has until November 2021 to meet the guidelines.

 

(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. Having 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 future years, and Mr. Ramil’s status in this regard may change based on the Board’s review and further determination at that time.

 

 

14             Emera Inc. — Management Information Circular 2019


MANAGEMENT INFORMATION CIRCULAR

 

 

 

 

 

Andrea Rosen

 

Age: 64

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 a member of Emera’s Audit Committee since May 2007. She was appointed Audit Committee Chair in April 2008. She 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. Previously, Ms. Rosen also served as Vice President of Varity Corporation from 1991 to 1994. 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 Director of Manulife Financial Corporation, a Canadian multinational insurance company and financial services provider. She is a Director of Ceridian HCM Holding Inc., a global human capital management software company. She is a former Director of Alberta Investment Management Corporation 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 Masters 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 the Board.

 

 

Board/Committee

Membership

 

  

Attendance   

 

  

Total

 

    

Public Company Board Membership

During the Last Five Years

 

 

•  Board member

•  Audit Committee
Chair

 

  

 

6 of 6  

5 of 5  

  

 

 

 

100%

100%

 

 

 

  

 

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

•  Manulife Financial Corporation
(August 2011 to present)

•  Hiscox Ltd.
(October 2006 to October 2015)

 

 

Total Compensation

 

 

            Fees earned in 2018 ($)  

 

  

All other compensation ($)  

 

  

Total ($)  

 

234,000   

 

  

 

N/A  

 

  

234,000   

 

 

 

DSUs Awarded and Held

 

 

2018 share-based  

awards ($)  

 

  

Total 2018 increase in value  

of all DSUs held ($)  

 

  

Market value of total  

DSU holdings ($)  

 

 

234,000   

 

  

 

180,392   

 

  

 

2,593,097   

 

 

 

Securities Held

 

Year  

 

    

Common  
shares  

 

    

DSUs  

 

    

 

Value of shares  
and DSUs ($)  

 

    

Status under share ownership

guidelines

 

 

 

 

2018  

2017  

2016  

 

 

 

 

  

 

 

 

14,336  

14,336  

14,336  

 

 

 

 

  

 

 

 

59,325  

51,356  

44,026  

 

 

 

 

  

 

 

 

3,219,722  

3,086,210  

2,649,051  

 

 

 

 

  

 

Ms. Rosen owns DSUs valued at 565% of the requirement under the Share Ownership guidelines; therefore, the guidelines are met.

 

 

 

Emera Inc. — Management Information Circular 2019            15


    

  

 

 

 

Richard Sergel

 

Age: 69

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 a member of the Management Resources and Compensation Committee since September 2014. He was a member of the Audit Committee from November 2010 to September 2014. He was 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 member of the Board 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”). 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 presently a Director of State Street Corporation. He also served on the Boards of the Edison Electric Institute, the Consortium for Energy Efficiency and the United Way of the Merrimac Valley.

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. His regulatory background is a distinct asset.

 

 

  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

 

    

 

 

6 of 6    

 

4 of 4    

 

3 of 3    

 

 

 

 

 

    

 

 

100%    

 

100%    

 

100%    

 

 

 

 

 

  

•  State Street Corporation (September 1999 to present)

 

 

 

  Total Compensation

 

     

Fees earned in 2018 ($)    

 

  

All other compensation ($)    

 

  

Total ($)    

 

     

251,431    

 

  

10,000    

 

  

261,431    

 

 

 

  DSUs Awarded and Held

 

2018 share-based    

awards ($)    

 

  

Total 2018 increase in value    

of all DSUs held ($)    

 

  

Market value of total    

DSU holdings ($)    

 

     

125,000  

 

  

107,715  

 

  

742,461  

 

 

 

  Securities Held

 

         

  Year  

 

  

Common
shares

 

    

DSUs

 

    

Value of shares
and DSUs ($)

 

   

Status under share ownership

guidelines

 

         
2018

2017

2016

    

5,500

4,000

4,000

 

 

 

    

16,986

13,511

10,235

 

 

 

    

982,863

822,667

646,127

 

 

 

 

Mr. Sergel owns shares and DSUs valued at 172% of the requirement under the Share Ownership guidelines; therefore, the guidelines are met.

 

 

 

 

16             Emera Inc. — Management Information Circular 2019


MANAGEMENT INFORMATION CIRCULAR

 

 

 

 

Jackie Sheppard

 

Age: 63

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 of Seven Generations Energy Ltd., a publicly traded energy company focused on Canadian natural gas development. She is also a Director of 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.

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)

 

 

    

 

6 of 6    

 

 

 

    

 

100%    

 

 

 

  

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

•  Cairn Energy PLC (May 2010 to December 2018)

 

 

 

 

  Total Compensation

 

     

Fees earned in 2018 ($)    

 

  

All other compensation ($)    

 

  

Total ($)    

 

     

400,000     

 

  

N/A     

 

  

400,000     

 

 

 

  DSUs Awarded and Held

 

     

2018 share-based    

awards ($)    

 

  

Total 2018 increase in value    

of all DSUs held ($)    

 

  

Market value of total    

DSU holdings ($)    

 

     

400,000   

 

  

335,503   

 

  

2,898,027   

 

 

 

  Securities Held

 

         

  Year  

 

  

Common
shares

 

    

DSUs

 

    

Value of shares
and DSUs ($)

 

   

Status under share ownership

guidelines

 

         
2018

2017

2016

    

11,947

11,947

11,947

 

 

 

    

66,301

54,545

43,561

 

 

 

    

3,420,220

3,123,794

2,519,508

 

 

 

 

Ms. Sheppard owns shares and DSUs valued at 600% of the requirement under the Share Ownership guidelines; therefore, the guidelines are met.

 

(1) Ms. Sheppard attended all Committee meetings in 2018 in her capacity as Board Chair.

 

 

Emera Inc. — Management Information Circular 2019            17


    

 

 

 

Jochen Tilk

 

Age: 55

Saskatoon, Saskatchewan

Canada

Director Since: 2018

Independent

 

LOGO

 

Skills and Experience

•  CEO/Senior Executive

•  Customer/Stakeholder

•  M&A/Growth Strategy

•  Governance/Other Directorship

•  Financial

 

 

 

Mr. Tilk has been a Director since July 2018. He became a member of the Audit Committee in November 2018.

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 a member of the C.D. Howe Institute, and is the former Chair of the board of directors of Canpotex Limited. He was a director of the Fertilizer Institute and the International Fertilizer Association.

He received his Masters 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 the Emera Board.

 

 

  Board/Committee

  Membership

 

  

Attendance    

 

    

Total    

 

    

Public Company Board Membership

During the Last Five Years

 

       

•  Board member

•  Audit Committee
member

 

 

 

    

 

4 of 4    

1 of 1    

 

 

 

 

    

 

100%    

100%    

 

 

 

 

  

•  AngloGold Ashanti Limited (January 2019 to present)

•  Nutrien Ltd. (PotashCorp from 2014 to 2018)

 

 

 

    Total Compensation

 

     

Fees earned in 2018 ($)    

 

  

All other compensation ($)    

 

  

Total ($)    

 

     

109,211     

 

  

N/A     

 

  

109,211     

 

 

 

    DSUs Awarded and Held

 

     

2018 share-based    

awards ($)    

 

  

Total 2018 increase in value    

of all DSUs held ($)    

 

  

Market value of total    

DSU holdings ($)    

 

     

84,571   

 

  

79,160   

 

  

79,160   

 

 

 

    Securities Held

 

         

    Year    

 

  

Common    
shares    

 

  

DSUs

 

    

Value of shares    
and DSUs ($)    

 

 

Status under share

ownership guidelines

 

         
2018    Nil      1,811      79,158  

Mr. Tilk owns shares and DSUs valued at 14% of the requirement under the Share Ownership guidelines. He has until July 2023 to meet the guidelines.

 

 

 

 

18             Emera Inc. — Management Information Circular 2019


MANAGEMENT INFORMATION CIRCULAR

 

Compensation of Directors in 2018

Purpose of Director Compensation

The compensation of Directors is designed to:

   

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

   

ensure alignment with Shareholders’ long-term interests; and

   

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 (DSUs)

Directors have the ability to elect to receive some or all of their cash compensation in the form of DSUs. In 2018, the annual retainer for each Director was $190,000, of which $125,000 was payable in 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 2018 was $400,000. This was comprised of $200,000 in DSUs, and the remainder in cash.

Compensation Rates for Directors

Listed below are the annual compensation rates for non-executive Directors. These rates are not applicable to Mr. Balfour, who is an employee of the Company.

 

Annual retainers and meeting fees for Directors in 2018

 

  

Cash amount ($)

 

    

DSUs ($)

 

    

Total ($)

 

 

Annual Chair’s retainer

     200,000        200,000        400,000  

Annual Director’s retainer

     65,000        125,000        190,000  

In-person meeting fee

           1,750  

Telephone meeting fee

           1,250  

Travel fee (if one-way travel is five hours or more)

           1,750  

Travel fee (if one-way travel is at least three hours but less than five hours)

           875  

Annual Audit Committee Chair’s retainer

           20,000  

Annual Audit Committee member’s retainer

           5,000  

Annual Management Resources and Compensation Committee Chair’s retainer

           15,000  

Annual Management Resources and Compensation Committee member’s retainer

           3,000  

Annual Nominating and Corporate Governance Committee Chair’s retainer

           10,000  

Annual Nominating and Corporate Governance Committee member’s retainer

           3,000  

Annual Health, Safety and Environment Committee Chair’s retainer

           10,000  

Annual Health, Safety and Environment Committee member’s retainer

           3,000  

 

 

Members of ad hoc committees receive meeting fees 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 Inc. — Management Information Circular 2019            19


 

Total Director Compensation in 2018

The following table sets out the total compensation earned by the Directors who served on Emera’s Board during 2018. Compensation is made up of applicable retainers and fees, at the rates described on the previous page, for attendance at Board and Committee meetings which a Director attended as a member or guest, for briefing meetings, education sessions and travel fees.

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 2018
   ($)(1)

   

 

All other
 compensation ($)

   

 

Total ($)

   

 

2018 Share
Based
Awards ($)(2)

   

 

Value of DSUs
 vested during 2018 
($)(3)

    

 

Change in
value of
DSUs held in
2018 ($)(4)

   

 

 Market value of
 total DSU
 holdings  ($)(5)

 
               
James Bertram     113,732         N/A               113,732         113,732           106,413            0         106,413   
               
Sylvia Chrominska     225,500         N/A               225,500         200,375           257,837            (90,087)         1,462,029   
               
Henry Demone     222,625         N/A               222,625         222,625           245,516            (45,589)         854,903   
               
Allan Edgeworth     240,500         N/A               240,500         240,500           351,617            (164,094)         2,545,067   
               
James Eisenhauer     219,000         N/A               219,000         219,000           315,808            (143,455)         2,233,368   
               
Kent Harvey(6)     247,290         N/A               247,290         125,000           119,644            (1,282)         136,794   
               
Lynn Loewen     223,625         N/A               223,625         223,625           264,558            (69,454)         1,192,949   
               
John McLennan     84,892         N/A               84,892         84,892           289,784            (276,654)         3,987,819   
               
Don Pether     227,375         N/A               227,375         227,375           316,508            (133,976)         2,107,364   
               
John Ramil(6)     246,472         N/A               246,472         246,472           251,021            (22,759)         555,252   
               
Andrea Rosen     234,000         N/A               234,000         234,000           348,304            (167,935)         2,593,097   
               
Richard Sergel(6)     251,431         10,000(7)       261,431         125,000           151,889            (44,181)         742,461   
               
Jackie Sheppard     400,000         N/A               400,000         400,000           513,841            (178,363)         2,898,027   
               
Jochen Tilk     109,211         N/A               109,211         84,571           79,160            0         79,160   

 

(1)

The “Fees earned in 2018” 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 2018 that was allocated to DSUs. DSUs granted in 2018 are based on the value of the Emera common share closing price on December 31, 2017 ($46.98).

(3)

This column shows the value of all DSUs received in 2018, including received as dividend equivalents during the year, multiplied by the December 31, 2018 Emera common share closing price of $43.71.

(4)

This column shows the change in value of all DSUs held by each Director at the beginning of the year as a result of the change to the Emera common share closing price from $46.98 at the beginning of the year to $43.71 on December 31, 2018.

(5)

This column shows the value of all DSUs held by each Director at the end of 2018 based on the December 31, 2018 Emera common share closing price of $43.71.

(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. 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.

 

20             Emera Inc. — Management Information Circular 2019


MANAGEMENT INFORMATION CIRCULAR

 

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

In order 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 a specified time frame. 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 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 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 elected to be paid in DSUs by (b) the fair market value 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 Inc. — Management Information Circular 2019            21


 

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.

 

22             Emera Inc. — Management Information Circular 2019


MANAGEMENT INFORMATION CIRCULAR

 

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 24
   

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

 

   Board of Directors
page 24
   
The Board and, on certain matters by delegation, its Committees oversee the Company’s risk management.   

Board of Directors
page 24

 

   

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

 

  

Position Descriptions
page 24

 

   

Directors receive an in-depth orientation when they become Board members. Annually, site visits are organized to operating facilities and offices. In addition, special areas of focus or interest are addressed at Board dinners and meetings. Board members are encouraged to continue to pursue education to familiarize them with the business, investments and key Company personnel.

 

   Orientation of Directors and Continuing Education
page 30
   

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 routinely reviewed by the Nominating and Corporate Governance Committee.

 

   Ethical Business Conduct
page 32
   
New Directors are recruited on the basis that they will make a strong contribution and have the background, skills and experience needed by the Board in view of the Company’s strategy.   

Nomination of Directors and Director Recruitment Process
page 25

 

   

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 29

 

   

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 33
   

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. We track our conclusions and follow up.

 

  

Board and Director Performance Assessments
page 27

 

 

Please read Emera’s entire Statement of Corporate Governance Practices on the following page for more important details about the Company’s governance
practices.

 

Emera Inc. — Management Information Circular 2019            23


 

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. The Board of Directors Charter was reviewed in 2018 to ensure it appropriately reflected the Board’s responsibility. That review resulted in minor clarifying amendments being made. The Charter as amended is attached to this Circular as Appendix A.

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 independence and integrity, strategic planning, risk management, leadership and succession, financial reporting, corporate communications, public disclosure and corporate governance. We encourage you to carefully review the Charter for more detail about the obligations of the Board in these areas.

Director Independence

All Emera Directors are independent from management, except for Mr. Balfour and Mr. Ramil. Mr. Balfour is the President and CEO. Mr. Ramil, who was President and CEO of TECO at the time it merged with Emera on July 1, 2016, is not considered independent. Mr. Ramil 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 the determination by the Emera Board having regard to the test set out below. The Board has determined that he should not be considered independent at this time, but this determination is subject to review by the Emera Board in future years, and Mr. Ramil’s status in this regard may change based on the Board’s review and further determination at that time.

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.

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. Mr. Sergel receives a retainer for being a member of the Board of Emera’s subsidiary Emera US Holdings Inc. 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.

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 provides advice and counsel to Directors and the President and CEO. The Chair participates in the recruitment of Directors and the assessment of their performance and of the Board as a whole. 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 in order 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 roles and responsibilities of the President and CEO are contained in his employment contract, which provides that he is chief executive of the Company. 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. In 2017, the Board announced that Mr. Chris Huskilson had provided notice of his intention to retire as CEO in 2018. Concurrently, the Board also announced it would appoint Mr. Balfour as CEO upon Mr. Huskilson’s retirement. The Board appointed Mr. Balfour a Director and the President and Chief Executive Officer of Emera effective March 29, 2018. During the transition period before Mr. Huskilson’s retirement, the Board regularly met independently with Mr. Huskilson and Mr. Balfour during its in-camera sessions to garner their feedback on the transition process. 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. Twelve Director nominees are being proposed for election at the 2019 Annual Meeting.

Mr. Allan Edgeworth is not a nominee for re-election at the 2019 Annual Meeting. Mr. Edgeworth has been a Director since November 2005. He has been Chair of the Health, Safety and Environment Committee since May 2017. He has been a member of the Management Resources and Compensation Committee since February 2006 and was Committee Chair from May 2010 to May 2016. Mr. Edgeworth was a member of the Audit Committee from April 2008 to May 2013. From May 2007 to April 2008, Mr. Edgeworth was a member of the Nominating and Corporate

 

24             Emera Inc. — Management Information Circular 2019


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Governance Committee. He also served as a Director of Nova Scotia Power Inc. from November 2005 to October 2006. Mr. Edgeworth’s extensive experience as a senior leader in the energy sector combined with his expertise in corporate governance has made him a valuable member of the Board.

Mr. Eisenhauer is not a nominee for re-election at the 2019 Annual Meeting. Mr. Eisenhauer has been a Director of the Company since May 2011 and a member of the Audit Committee since June 2016. He is the former Chairman of the Board of Directors of Emera’s subsidiary, Nova Scotia Power Inc., having served on its Board from 2008 to 2016.

Mr. Eisenhauer will re-join Nova Scotia Power’s Board of Directors effective May 15, 2019, where he will assume the role of independent Lead Director. His professional knowledge and experience, combined with his executive leadership in manufacturing and distribution businesses, are valuable assets to the Nova Scotia Power Board. Mr. Eisenhauer has extensive governance skills and experience, and his leadership role in the Nova Scotia business community provides him with valuable stakeholder understanding.

Nomination of Directors and Director Recruitment Process

The 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 for election as Directors at Emera’s Annual Meeting of Shareholders, the NCGC evaluates the size of the Board and the mix of skills and experience of its Directors, its diversity overall and the level of representation of women on the Board. Director nominees must, in the opinion of the members of the NCGC, be able to 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 current age and tenure of current members and in light of the Board’s overall policy of ensuring refreshment, diversity of thought and smooth Board succession. In recruiting new Directors, the NCGC considers the background, skills and experience desired for Directors in view of the Company’s strategy and activities. It develops a plan for the recruitment of additional Director nominees who can provide those characteristics.

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 as a Director, and keeping in mind the age of Directors. The average tenure of all of Emera’s 12 Director nominees is 5.69 years. Three nominee Directors have served on the Board for more than a decade and two nominee Directors have served for less than a year. 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 fresh perspective and approach to the Company’s Board table.

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 earlier in the section of this Circular, 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 a number of 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 which entail regularly assessing 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.

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 is a mechanism the Board possesses to provide for Board renewal and will continue to serve the Company’s best interests, providing for appropriate renewal of the membership on the Board.

In November 2016 the Board of Directors adopted a governance practice intended to provide for Board renewal in light of 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 read as follows:

Board Renewal Principles

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

(a)

Age: as Directors approach 70 years of age, the NCGC will assess 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 will begin the replacement process.

(b)

Tenure: the length of time that a nominee has served on the Company’s Board of Directors shall be considered 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 shall be determined and considered.

(d)

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

(e)

Other relevant factors: the NCGC shall consider 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 will fulfill the fundamental responsibility of providing stewardship and good governance for the Company.

 

Emera Inc. — Management Information Circular 2019            25


 

In practice, as a Director approaches age 70, the Board will assess 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 a smooth 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 2019 Annual Meeting. Mr. Pether will be 71 at the time of the Company’s 2019 Annual Meeting. He has been a Director for ten years and is Chair of the NCGC. The Committee considered the average age of all of the Company’s Director nominees for election at the 2019 Annual Meeting, which will be 63.17 years (in 2018 it was 63.1 years), and the average tenure of all of the Company’s Director nominees as of the 2019 Annual Meeting, which will be 5.69 years (in 2018 it was 6.3 years). Also considered was Mr. Pether’s role as Chair of the NCGC, where he plays a central role in stewarding the longer-term Board succession process, and the need for continuity through this longer-term succession plan. In applying the Board Renewal Principles as described, the NCGC has recommended to the Board of Directors that Mr. Pether continue to serve as a Director because of his extensive experience with the Company, and because of the support and continuity he provides to the NCGC as Committee Chair through this Board renewal process. The Emera Board of Directors accepted the recommendation of the NCGC. As a result, Mr. Pether has been included in the list of Director nominees for election at the Meeting.

Directors Meet Without Management

There were 21 Emera Board and Committee meetings during 2018. The Board and each Committee has 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 such 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 also 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 to the exclusion of all management, including the President and CEO. See Board Dinner Sessions for more information.

Board Dinner Sessions

Board dinner sessions are scheduled the evening prior to regularly scheduled Board meetings. Board dinners are treated as an opportunity to accomplish a number of important governance objectives, including:

   

Meeting as Directors in an atmosphere that is not a Board meeting. The Board’s practice is to have one dinner each year at which only the non-executive Directors attend. Based upon Director feedback from the 2018 Board Assessment, there will be two such meetings commencing in 2019;

   

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 in order to advance the succession planning for the Company; and

   

Strengthening Directors’ collegial working relationship.

Strategic Planning

Oversight and guidance on the Company’s strategy is one of the primary roles of the Board. Management, led by the President and CEO, collaborates with the Board of Directors each year to develop, review and update the Company’s strategic plan. The strategic plan determines the annual and longer-term objectives for the Company.

In 2018, the Board dedicated a portion of each scheduled meeting to receiving an update on the Company’s strategy. A significant component of every regularly scheduled Board meeting is dedicated to the discussion of strategic matters. Directors use such Board meeting time to evaluate progress made in executing the Company’s strategy, including reviewing near- and longer-term risks and opportunities relevant to its corporate strategy.

A full-day Board off-site meeting was held in July 2018 to deal with the Company’s strategy. This off-site meeting: (i) analyzed trends in the Company’s industry; (ii) reviewed the Company’s approach to innovation; (iii) examined the current financial position and forecast; and (iv) considered the Company’s opportunities and challenges in various regions. At its next regularly scheduled meeting after the strategy off-site session, the Board focused upon the strategy of a select subsidiary business. As such, at its September meeting, the Board undertook a review of its behind-the-meter strategy and reviewed in greater detail the strategy of one of its operating subsidiaries.

An example of the Board’s oversight of strategy was its review of the factors contributing to long-term value creation and above-average performance in the utilities sector, including the evolution of North American capital markets. This review led to the Board’s approval of a change in Emera’s annual dividend growth target and the announcement that preferred funding for its capital investment profile included the proceeds from select asset sales.

With respect to current strategic priorities, the Company’s emphasis has not changed, and remains focused on: (i) investing in delivering cleaner, affordable energy through investing in renewables, investing in natural gas as a cleaner fuel for electricity generation and customer use, and investing in electricity transmission to deliver new renewable energy to market; (ii) identifying opportunities to invest in the transition from higher carbon methods of electricity generation to lower carbon alternatives, including the creation of a separate wholly owned subsidiary focused exclusively on innovation; and (iii) maintaining its focus on customer solutions and on what we believe the utility of the future needs to look like.

 

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Board and Director Performance Assessments

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

Assessment Process

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. An in-camera Board session is held to consider the report. Issues arising from the assessment are identified, an action plan is developed and progress is monitored throughout the year with oversight on that process by the NCGC.

2017 Assessment Findings and Action Plans to Address Findings

The 2017 Board and Director Performance Assessment resulted in several priority actions for 2018. With the assistance of the NCGC, the Board Chair reviewed progress made to address those priorities. This progress was reported to the Board, with significant areas including:

(a)

Corporate Strategy: a strategic and risk framework is applied to business opportunities and potential investments, and the Company’s decision-making process regularly applies comprehensive macro analysis and peer review, supported by recently enhanced planning and modelling capabilities.

(b)

Strategies and Plans at the Operating Subsidiaries: Emera’s Board receives a subsidiary operations report at each scheduled Board meeting, including updates on large projects of operating subsidiaries. The Board also receives updates about subsidiaries’ strategies. Director’s annual Board education sessions include meetings with subsidiary management, facility tours and market presentations. The Board conducted reviews of its subsidiary holdings through a strategic lens, leading to key decisions and action in 2018. This process will continue, representing important focus on capital allocation and overall strategy in order to position the Company’s utilities to meet the future needs of customers, and to ensure they are ready and able to compete on price, reliability and customer service, while focused on achieving world class safety and remaining an employer of choice in order to attract and retain the best possible talent.

(c)

Organizational Structure and Capacity: the Company has reviewed its organizational structure and operating subsidiary governance model in order to better secure alignment. TECO Services, Inc.’s role in the organization has evolved within the Emera group of companies in order to provide shared services with regulatory recovery of costs incurred based upon a well-developed allocation model. The Board will continue to receive updates on the Company’s learning and education initiatives, leadership development and succession programs, the overview of corporate costs, and the Company’s regulatory and stakeholder engagement program.

(d)

Board and Committee Effectiveness: Director education, including site visits, continues to provide Board members with important opportunities to gain exposure to employees of the Company’s operating subsidiaries in the facilities and communities where they work. The 2018 site visit to Tampa, Florida provided Directors with an opportunity to meet employees of Tampa Electric Company and Peoples Gas System.

(e)

Corporate Governance: A framework for how the Company governs, promotes and measures corporate culture was reviewed, and work will continue to be done in this area.

(f)

Board Composition and Succession: In accordance with the Board’s Renewal Principles and anticipated retirements, it developed a five-year Board succession plan. In accordance with this plan, recruitment efforts resulted in the appointment in July 2018 of two new Directors, James Bertram and Jochen Tilk. With the addition of new Directors and the anticipated retirement of others, the NCGC and the Board Chair undertook a review of Committee Chair positions and Committee membership. As a result of that review, a plan to update Committee composition has been determined and will be implemented to support the ongoing valuable work of these Committees under the leadership of their respective Committee Chairs.

2018 Board Director/Board Chair Performance Assessment

The Chair of the Board interviewed each non-executive Director as part of the 2018 Board and Director Performance Assessment. A series of questions was sent to each Director for advance consideration. The questions pertained to a number of themes, including:

 

Emera’s strategy and business;

 

Organizational structure and capacity;

 

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; and

 

The CEO’s 2018 evaluation, and the 2019 goals and objectives of the CEO.

The assessment of the Chair of the Board was conducted in a meeting of all Directors that excluded the Board Chair, and was led by the Chair of the NCGC. Directors were asked to provide feedback directly to, and were given an opportunity to discuss the assessment of, the Chair of the Board in a one-on-one format with the Chair of the NCGC in advance of the meeting.

2018 Assessment Findings

The principal areas of focus which emerged from the 2018 Board and Director Performance Assessment included: corporate strategy; management structure, capacity and succession; and corporate governance.

 

(a)

Corporate Strategy

Balance sheet management activities were central to discussions on strategy in 2018, insofar as a healthy balance sheet was seen as fundamental to underpinning execution of the Company’s business plans. The Board and management have been quick to understand and manage the perspectives of capital markets and rating agencies.

 

Emera Inc. — Management Information Circular 2019            27


 

Solid execution and delivery of large accretive capital projects in Emera’s core businesses, such as the Maritime Link project of Emera Newfoundland and Labrador Holdings in Atlantic Canada, and the solar generation and Big Bend modernization projects of Tampa Electric Company in Florida, have been and remain strategic imperatives. The Board concurrently challenges management to think longer term in assessing other growth opportunities in each operating subsidiary.

 

(b)

Management Structure, Capacity and Succession

The integration of TECO Energy was an area of principal focus, and continued improvements were seen in the areas of safety, workplace transparency and collaboration.

The Board continued to review short- and longer-term senior management succession plans. It has a keen interest in having first hand knowledge of and familiarity with high-potential employees.

 

(c)

Corporate Governance

Emera upholds high governance standards throughout the organization. All Board members agree that good governance is foundational to good decision making and good business. The Board operates effectively, and the boardroom chemistry and culture is strong.

In anticipation of approaching retirements, and recognizing Emera’s new size and complexity, the Board has continued implementation of a five-year Director recruiting plan. Work will continue in 2019 under that plan. In the absence of term limits, the Emera Board’s application of renewal principles has allowed for more flexibility and a more orderly process for the transition in Board and Committee composition.

Board Diversity

To ensure that there are a significant number of women on the Company’s Board of Directors, the Company recruits Board members under a formal written corporate governance practice, adopted by the NCGC in 1994, which requires that a minimum percentage of the members of the Board of Directors are women. In November 2018, on the recommendation of the NCGC, the Board of Directors increased to 30 per cent, from 25 per cent, the minimum percentage of women constituting the Board. The list of Director nominees for the 2019 Annual Meeting includes four women out of 12 Director nominees, or 33 per cent, which exceeds this minimum requirement. In each of the last 10 years, women have represented at least 30 per cent of the Director nominees for election at the Company’s annual Shareholder meetings.

The NCGC reviews the criteria for selecting Director nominees in light of this governance practice. This governance practice reflects the Board’s view that gender diversity is an important part of fostering diversity of perspective and experience around the Board table, leading to improved overall performance of the Board and its Committees. Diversity extends beyond gender. Through the Board assessment process and discussion on the findings, it is clear Board members believe that in light of the many changes facing the industry, whether through technology, policy or otherwise, diversity of thought at the Board level is an important strategic objective of the Board and the Board succession process.

Representation of Women in Executive Officer Appointments

While Emera does not have targets regarding women in executive officer appointments, management is of the view that gender diversity among the senior executive team within the Emera group of companies serves the best interests of the Company in the following ways:

 

It is important that Emera’s executive ranks reflect our diverse customer base.

 

Gender diversity will help the Company better understand the needs of its customer base.

 

The available workforce is increasingly made up of women. As baby boomers retire and as a competitive labour market is anticipated, Emera needs to access talent from the broadest recruitment pool.

 

Leadership in diversity will make the Company an employer of choice and help us to recruit, retain, and engage high-performing employees.

 

It is demonstrable that business performance improves with greater gender diversity; it is good for business.

Among the executive officers(1) of Emera Inc. and its major subsidiary,(2) Tampa Electric Company, 15 are female, representing 35 per cent. Of Emera’s 12 operating subsidiaries, women are the leaders of five, namely: Tampa Electric Company, Nova Scotia Power Inc., Emera Energy Inc., TECO Services, Inc. and Dominica Electricity Services Ltd.

Emera monitors the progression of women into leadership positions within Emera and its subsidiary companies.

With a view to fostering diversity within Emera, the Company’s management does not believe that targets are the right approach. Rather, management continues to be focused on ensuring Emera’s hiring and pay practices promote equity between men and women. Progress is being made. In 2017 and 2018, Emera’s largest subsidiaries hired an almost equal number of men and women. Emera and its subsidiaries have also recently focused efforts to reach women earlier in their lives through opportunities such as a new scholarship program focused on supporting women and through an engineer-in-training program. Emera’s plan to address gender and pay equity aligns with its inclusion and diversity strategy, and includes: (a) annual analysis of pay equity; (b) continued development and promotion of programs such as the engineer-in-training program that are focused on increasing female participation in the energy industry, particularly for traditionally male-dominated roles; and (c) examination of recruitment strategies to limit pay gaps at entry into the organization and monitoring of the gender of new hires.

 

(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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Compensation

Executive Compensation

On the recommendation of the 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.

The annual retainer for Directors in 2018 was $190,000 per annum, payable as follows:

 

$65,000 cash; and

 

$125,000 in DSUs.

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

For more details on total compensation received by Emera Directors in 2018, see Compensation of Directors in 2018.

Annual Review

The NCGC annually reviews the compensation of Directors to ensure it is appropriate. The last increase in Director compensation occurred on January 1, 2017.

The NCGC reviews the compensation practices of publicly traded companies similar to Emera’s size and complexity 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) Ltd., 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. 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.

Based on this approach and on such annual review, the NCGC recommended no change in 2019 to the retainer and equity compensation for Emera Directors or the annual retainer for the Chair of the Board.

Director Share Ownership Guidelines

Under guidelines established by the Board of Directors, within a prescribed time frame, each Director must own Emera common shares and DSUs with a market value of three times the annual Board retainer. Based on the annual retainer for Emera Directors noted above, under these guidelines, each Director must own Emera shares or DSUs, or a combination of the two, worth $570,000 within five years following their appointment date or within five years of any change to the Director’s compensation, whichever is the later date.

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, over 65 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 $125,000 per annum, and in many cases, Directors have elected to receive DSUs in lieu of all cash compensation they would otherwise be entitled to as Emera Directors. Members of Emera’s Board of Directors support Directors’ ownership of shares and DSUs, believing that it contributes to the alignment of the interests of Directors with those of Emera Shareholders.

Majority Voting for Election of Directors

The confidence of Shareholders in the actions of the Board and management are 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 at, 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.

 

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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.

Orientation of Directors and Continuing Education

For each new Director to be effective in their roles, they must be knowledgeable about the Company and its strategy, strengths and challenges.

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, 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 oversight function of Directors is enhanced when they are well informed about the Company’s business and its industry. Management 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 senior management updating Directors about market and industry conditions and trends that may impact the Company’s business and influence its strategy. Annually, the Board is also provided with opportunities to make site visits to operational facilities to assist Directors to get to know leaders, understand management structure and more fully understand the business. From time to time, the Board receives specialized presentations on various matters of significance to the Company.

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 shall request the approval of the Board Chair to attend a particular education session and shall receive reimbursement of expenses in accordance with the Guideline.

Directors participated in education sessions and received education materials about specific topics in 2018 as follows below:

 

 

Education Presentations

 

  

Date

 

  

Participants

 

Facilities site visit and operations presentations:

Tampa Electric Company

Peoples Gas System

   April 4-6   

Jackie Sheppard

Lynn Loewen

Rick Sergel

Jim Eisenhauer

John Ramil

 

     

 

Presentation provided by JD Power on Customer trends

   April 4-6   

Jackie Sheppard

Lynn Loewen

Rick Sergel

Jim Eisenhauer

John Ramil

 

     
Presentation provided by external speaker on major trends impacting the energy industry    July 9   

Attended by all Board Members

 

(Board dinner)

     

Presentation provided by internal speaker on innovation and new opportunities behind the meter

 

   July 10    Attended by all Board Members
     

Presentation by external safety consultant on safety systems and safety governance

 

   September 27    All members of the Health, Safety and Environment Committee and Board Chair
     

Presentation by external compensation consultant on executive compensation trends in 2018

 

   September 27   

All Management, Resources and Compensation

Committee members and Board Chair

     
Presentation on Peoples Gas Strategy    September 28   

Attended by all Board Members

 

 

30             Emera Inc. — Management Information Circular 2019


MANAGEMENT INFORMATION CIRCULAR

 

 

Presentation on best practices in corporate governance    September 27  

Nominating and Corporate Governance Committee

members and Board Chair

 

 

Facilities site visit and operations presentations:

Tampa Electric Company

Peoples Gas System

  

 

October 17-19

 

Jackie Sheppard

Sylvia Chrominska

Andrea Rosen

Al Edgeworth

Henry Demone

Kent Harvey

Jim Bertram

Jochen Tilk

 

Presentation provided by JD Power on customer trends

  

 

October 17

 

Jackie Sheppard

Sylvia Chrominska

Andrea Rosen

Al Edgeworth

Henry Demone

Kent Harvey

Jim Bertram

Jochen Tilk

     
Presentation on best practices in corporate governance:
term limits
   November 15  

Nominating and Corporate Governance

Committee members and Board Chair

 

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 directly related to the business of the Company and the performance of their duties as a Director of the Company.

 

Emera Inc. — Management Information Circular 2019            31


 

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 in order to update the content in keeping with best practices. As such, the Code of Conduct was reviewed in 2018. As a result of this review, certain revisions were made, including: adding language to emphasize management’s accountability for both encouraging and taking action to support Emera’s speak-up culture; adding language addressing important contracting differences among affiliates; and updating certain language consistent with changes to the Respectful Workplace, Privacy and Information Management policies; and making other language changes to clarify the obligations under the Code. The revisions were effective January 2019.

Employees are encouraged under the Code to, in good faith, seek advice, raise concerns, or 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.

Reports under the Code of Conduct are addressed by the Company, and on a quarterly basis the Internal Audit department informs the Audit Committee of all reports and their status.

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 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 and 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 will be 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 business conduct helpline, called “The Ethics Hotline”, hosted by an external service provider. The Ethics Hotline is available to employees to report allegations of conduct not in compliance with the Code of Conduct.

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.

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 reviewed by the Board to determine 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.

Risk Management

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

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 Nominating and Corporate Governance Committee. 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 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.

 

32             Emera Inc. — Management Information Circular 2019


MANAGEMENT INFORMATION CIRCULAR

 

 

On a quarterly basis, the Board receives and reviews a risk dashboard, prepared by the Company’s Enterprise Risk Management Committee. The risk dashboard identifies strategic risks, and includes management action plans for the highest risks. Further, a comprehensive and ongoing risk assessment is part of every project the Company undertakes. The Board is also responsible for reviewing Emera’s annual insurance program, its uninsured exposure, and its business continuity and disaster recovery plans.

The Board also annually evaluates the operation and effectiveness of the Board of Directors, its Committees and the Chair of the Board. In the course of that evaluation, the question of whether the Board has examined the key risks to the Company’s strategy and business plan is assessed. More information about this process is set forth 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 Committee 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 long-term value, (c) pay and performance not appropriately aligned, 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.

Health, Safety and Environment Committee (HSEC)

The HSEC is mandated to review 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.

Operating Subsidiaries Boards of Directors

Oversight of risk management also occurs at the level of operating subsidiary boards of directors, most of which include independent directors that are not part of Emera’s or the operating subsidiary’s management team.

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 may establish ad hoc committees.

Audit Committee

The Audit Committee is comprised of:

Chair: Ms. Rosen

Members: Mr. Eisenhauer, Mr. Harvey, Ms. Loewen 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 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’ Report or the performance of other audit, review or attest 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 internal auditor also reports directly to the Audit Committee, and the Committee oversees the appointment, replacement or termination of the internal auditor.

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

 

Emera Inc. — Management Information Circular 2019            33


 

Health, Safety and Environment Committee (HSEC)

The HSEC is comprised of:

Chair: Mr. Edgeworth

Members: Ms. Loewen, Mr. Pether 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, conformance with industry standards and best practices. It will also review 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 incidents respecting the Company’s assets or operations will be reviewed by the HSEC, including those involving personnel, and 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. Edgeworth, Mr. Demone and Mr. Sergel

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 total compensation and incentive compensation plans and equity-based plans. It approves grants of stock options, performance share units (PSUs) 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.

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.

 

34             Emera Inc. — Management Information Circular 2019


MANAGEMENT INFORMATION CIRCULAR

 

Nominating and Corporate Governance Committee (NCGC)

The NCGC is comprised of:

Chair: Mr. Pether

Members: Mr. Demone and Mr. Sergel

The NCGC assists the Board with a variety of matters relating to corporate governance. These duties include responsibility for providing 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. 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 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.

Committee Changes

Having regard to the departure of Mr. Edgeworth and Mr. Eisenhauer from the Board, the composition of the Committees was reviewed. As a result of this review, changes in Committee membership were recommended by the Board Chair and the NCGC and have been approved by the Board. The following Committee appointments are intended to be effective following the 2019 Annual Meeting:

 

     
Committee   Committee Chair   Committee Members
Audit Committee   Andrea Rosen   Kent Harvey, Lynn Loewen, Richard Sergel and Jochen Tilk
     
Health, Safety and Environment Committee   James Bertram   Kent Harvey, Lynn Loewen, Donald Pether and John Ramil
     
Nominating and Corporate Governance Committee   Donald Pether   Henry Demone, Andrea Rosen and Richard Sergel
     
Management Resources and Compensation
Committee
  Sylvia Chrominska   James Bertram, Henry Demone and Jochen Tilk

 

Emera Inc. — Management Information Circular 2019            35


 

Communication with Directors and Shareholder Engagement

The Directors are always interested in receiving Shareholders’ views about the Company, its governance and its operation. The Board oversees systems for receiving feedback from Shareholders and it monitors feedback received by the Company. In addition, the Board believes that it is important from time to time, when appropriate, to have engagement directly with its Shareholders to allow Shareholders to express their views. The Board also recognizes that Shareholder engagement is an evolving practice in Canada and globally 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 mailing (by regular mail or other means of delivery) to the address set forth in this table under “Contact Information”.

 

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,

 

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

 

in a sealed envelope marked “Private and Confidential – Attention, Chair of the Board of Directors of Emera Inc.”

 

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, 2018.

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.

 

36             Emera Inc. — Management Information Circular 2019


MANAGEMENT INFORMATION CIRCULAR

 

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

Dear Fellow Shareholder:

Emera is committed to creating sustainable value for its Shareholders. Value generation is significantly influenced by the quality of our executive team and their ability to lead and motivate all employees to act in the best interests of Shareholders and customers. A fundamental principle of Emera’s compensation philosophy is that our compensation programs should 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 measure whether Shareholders are experiencing strong value for their investment. We believe that aligning the interests of our executives with the interests of our Shareholders is of the utmost importance, which is why we require executives to hold significant equity in the Company. Our share ownership guidelines formalize our belief that executives must also be Shareholders and maintain a material 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. The Committee oversees all aspects of executive compensation as part of our ongoing efforts to meet the expectations of our Shareholders, customers, and regulators. The Committee carefully assesses and makes recommendations to the Board on how performance measures and targets are set. These measures and targets reflect the Company’s core values, as well as 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, 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 2018 performance, and our decisions relating to executive compensation.

Shareholder Engagement

In keeping with our ongoing commitment to strong corporate governance practices, we held our annual “Say on Pay” advisory vote at our 2018 Annual General Meeting that allowed Shareholders to indicate whether they agreed with Emera’s compensation practices and policies. Shareholders voted 98.5 per cent in favour of our approach to executive compensation. We will again be presenting a “Say on Pay” non-binding advisory resolution at this year’s Annual General Meeting. 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.

CEO Transition

At Emera, succession planning is a dynamic, ongoing process of systematically identifying, assessing and developing leadership competencies and business skills. The Committee assists the Board in the succession planning process with respect to the President and CEO and is responsible for overseeing succession planning for other senior management. The Board and the Committee undertake this process on an annual basis.

As a result of our comprehensive succession planning process, in 2018 the Company saw a smooth transition from former President and CEO Chris Huskilson, who spent more than 13 years in the role, to our current President and CEO, Scott Balfour.

2018 Compensation Decisions

Our compensation philosophy targets the median level of compensation in the market. At the end of 2017, the Committee reviewed benchmarking analyses from both Hugessen Consulting Inc., the Board’s independent compensation advisor, and Mercer (Canada) Ltd, management’s external compensation advisor, using the Company’s benchmarking comparator group. 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. The Committee will continue to monitor market trends to maintain our competitive positioning.

In 2018, the Committee conducted a review of the Company’s long-term incentive plans to determine how Emera compared to general market practice with respect to executive entitlements under various departure scenarios and how they could be structured to assist in workforce planning and retention. Stemming from this review, the Committee amended both the Performance Share Unit Plan and Senior Management Stock Option Plan, and also revised the restrictive covenants and termination provisions in the Company’s executive contracts. The plan changes take effect with the 2019 long-term incentive grants, and the updated executive contracts are being rolled out for current executives. These changes will increase alignment with market practice and lead to more predictable succession planning for the Company, without adding any materials costs. More information on these plan changes can be found in Long-Term Incentive Program.

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. Notwithstanding this positive result, we will continue to diligently monitor our programs in order to maintain our high governance standards.

 

Emera Inc. — Management Information Circular 2019            37


 

Rewarding Results

Emera had an exceptional 2018, delivering record adjusted earnings and operating cash flow per share and making significant progress advancing the Company’s organic growth strategy in Florida and Nova Scotia. Some of the Company’s key accomplishments in 2018 include:

 

   

Adjusted 2018 net income was $671 million, or $2.88 per common share, compared with adjusted net income of $524 million, or $2.46 per common share, in 2017 (reported 2018 net income was $710 million, or $3.05 per common share, compared with net income of $266 million, or $1.25 per common share, in 2017).(1)

   

In 2018, operating cash flow, before changes in working capital, increased $509 million, or 39 per cent, to $1,806 million, compared with $1,297 million in 2017.

   

The $1.6 billion Maritime Link Project went into service on January 15, 2018, and was delivered on-time and on-budget.

   

We announced an $850 million USD investment to modernize the Big Bend facility in Tampa, supporting Emera’s decarbonization strategy and highlighting Tampa Electric’s strong growth potential.

   

Emera was named one of Canada’s Top 100 Employers by The Globe and Mail, recognizing the Company’s commitment to being an employer of choice.

   

We were recognized by Corporate Knights as one of their Top 50 Best Corporate Citizens for our continued work on sustainability.

A central tenet of Emera’s executive compensation philosophy is that a significant portion of executive compensation must be at risk and linked to the achievement of objectives that measure whether Shareholders are experiencing strong value for their investment. Recognizing Emera’s performance against objectives established for the 2018 Corporate Balanced Scorecard, the Board approved an annual Short-Term Incentive Plan payout of 166.8 per cent of target. A full description of the 2018 Scorecard metrics and results is provided in 2018 Short-Term Incentive Results.

Our Long-Term Incentive Plan, which consists of performance share units (PSUs) 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 2016 PSU grant, which had a performance period from January 1, 2016 to December 31, 2018, measured Emera’s Total Shareholder Return (TSR) relative to the total return of the S&P/TSX Capped Utilities Index (the Index). Although Emera’s TSR outperformed the TSR of the Index by almost six per cent in 2018, Emera’s annualized TSR over the three-year performance period trailed the Index by one per cent and, as a result, the performance factor applied to the 2016 PSU grant was 0.65, well below target. More details are provided in Performance Share Unit Plan. 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 Mr. Huskilson from January 2009 to December 2017, and the compensation paid to Mr. Balfour in 2018, 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). Once again, the analysis concluded there was close 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 2018 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.

 

38             Emera Inc. — Management Information Circular 2019


MANAGEMENT INFORMATION CIRCULAR

 

Sustaining Shareholder Value

Emera continues to grow and diversify its businesses. Our financial results demonstrate that all of Emera’s operations throughout North America and the Caribbean are playing an important role in the Company’s overall success. The significant accomplishments, both financial and non-financial, referenced in this Circular demonstrate the strength of our team of leaders and employees who will help ensure the Company is well positioned for the exciting period of growth and opportunity that lies ahead of us. We were pleased to see Emera rank in the top five companies in Canada for the fifth consecutive year in The Globe and Mail’s 2018 Board Games, an annual corporate governance rating compiled by the Report on Business. We were also the proud recipient of the Canadian Coalition for Good Governance 2018 Governance Gavel Award for excellence in Shareholder communications.

We remain confident that our executive compensation programs work appropriately to retain and motivate executives, and provide rewards that are consistent with the Company’s performance level. We will continue to monitor our practices and industry trends and adjust our practices accordingly. 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, as always, 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

 

in a sealed envelope marked “Private and Confidential –
Attention, Chair of the MRCC of Emera Inc.”.

  

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

 

in a sealed envelope marked “Private and Confidential –
Attention, Chair of the Board of Directors of Emera Inc.”.

 

 

Sylvia Chrominska

  

 

Allan Edgeworth

  

 

Richard Sergel

  

 

Henrpy Demone

  

 

James Bertram

Director and Chair of the Management Resources
and Compensation Committee
   Director and Member of the Management Resources and Compensation Committee    Director and Member of the Management Resources and Compensation Committee    Director and Member of the Management Resources and Compensation Committee    Director and Member of
the Management
Resources and Compensation Committee
                     

(1) Adjusted net income and adjusted earnings per common share do not have standardized meaning under USGAAP. Emera calculates these non-GAAP measures by adjusting reported net income and reported earnings per common share for specific items the Company believes are significant, but not reflective of underlying operations in the period. Adjusted amounts exclude the effect of mark-to-market (MTM) adjustments and the impact in 2017 of US tax reform, signed into law on December 22, 2017 in the US Tax Cuts and Jobs Act of 2017. The MTM adjustments are a result of the following: the MTM adjustments related to Emera’s held-for-trading 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; the amortization of transportation capacity recognized as a result of certain Emera Energy marketing and trading transactions; the MTM related to an interest rate swap in Brunswick Pipeline; and the MTM adjustments related to equity securities held in Emera Caribbean and Corporate and Other. The US tax reform adjustment is a result of the revaluation of US non-regulated net deferred income tax assets as a result of the US federal corporate income tax rate reduction from 35 per cent to 21 per cent that was enacted in December 2017. For the MTM valuation adjustments, management believes excluding from net income the effect of these valuations and changes thereto, until settlement, better aligns the intent and financial effect of these contracts with the underlying cash flows and the 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. Due to the enactment of the US Tax Cuts and Jobs Act of 2017, the Company recorded a non-cash income tax expense resulting from the provisional revaluation of the existing US non-regulated net deferred income tax assets in Q4, 2017. No further adjustments were recognized in 2018 and the Company has completed its accounting for this revaluation. This provisional revaluation of an existing asset is not the result of any operational or market-driven event. Management therefore believes excluding from net income the effect of this provisional revaluation better distinguishes the ongoing operations of the business, and allows investors to better understand and evaluate the Company. Refer to the Non-GAAP Financial Measures section of our Annual Management’s Discussion and Analysis as at February 15, 2019 for further discussion of these items.

 

Emera Inc. — Management Information Circular 2019            39


 

Statement of Executive Compensation

Compensation Philosophy

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

 

 

reward Emera’s executives for sustained increases in Shareholder value;

 

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

 

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

Programs include 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 attract and retain high-quality talent. Emera’s executive compensation program is designed to generally provide total target compensation at the median or 50th percentile 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 (NEOs), is comprised of base salary, target short-term incentive and target long-term incentives linked to total Shareholder value.

Pay-for-Performance

A central tenet of Emera’s executive compensation philosophy is that a significant portion of executive compensation must be 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, employee and safety objectives that, if achieved, add value to the Company.

The incentive compensation plans are designed to pay larger amounts for superior performance and smaller 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 recommends to the Board of Directors for approval. The Board Chair, in collaboration with the MRCC, 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. Management 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 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.

 

40             Emera Inc. — Management Information Circular 2019


MANAGEMENT INFORMATION CIRCULAR

 

Compensation Program

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

 

 

Base Salary (page 50): 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 for the position and the performance and contribution of the individual.

 

 

Short-Term Incentive Program (page 50): Short-term incentive objectives are set forth in annual scorecards and consist of key objectives linked to the Company’s corporate strategy. These scorecards establish measurable financial, employee and health and safety objectives that, if achieved, are designed to add value to the Company.

 

 

Long-Term Incentive Program (page 54): Consists of performance share units (PSUs) 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 62): The Pension Plan consists of both defined benefit and defined contribution components and a supplemental employee retirement plan, all of which are governed by a pension oversight governance framework.

 

 

Other Executive Benefits (page 67): As an important part of competitive compensation, the Company also offers market competitive non-cash compensation components such as group benefits, vacation, wellness incentives and an Employee Common Share Purchase Plan.

 

 

Emera Inc. — Management Information Circular 2019            41


 

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 of the Company’s executive compensation plans and programs. Current members of the MRCC are:

 

Ms. Chrominska (Chair);

 

Mr. Edgeworth;

 

Mr. Sergel;

 

Mr. Demone; and

 

Mr. Bertram

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.

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 General Meeting, which allows Shareholders to indicate whether they are in agreement with Emera’s compensation practices and policies (98.5 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.

 

 

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.

 

 

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.

 

 

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 share awards, 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.

 

 

42             Emera Inc. — Management Information Circular 2019


MANAGEMENT INFORMATION CIRCULAR

 

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 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 equity compensation plans and any changes to such plans.

The Board Chair collaborates with the MRCC in assessing the performance of the President and CEO on an annual basis.

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. 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 interests and 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 potential payouts, clawback provisions, an anti-hedging policy and share ownership requirements are part of the Company’s overall plan design.

 

 

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.

 

 

Emera Inc. — Management Information Circular 2019            43


 

Risk Assessment

In 2018, the MRCC conducted its annual compensation risk review of its executive compensation programs and policies. To assist in the review, Management engaged Mercer (Canada) Ltd. (“Mercer”) to evaluate the previous year’s comprehensive risk assessment that Mercer conducted for any material changes over the course of the year, including the changes the Company made to its long-term incentive program as described in Changes to the Long-term Incentive Plans. 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 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 any 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. With input from its independent compensation advisor, Hugessen Consulting Inc., 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.

Succession Planning and Leadership Development

The MRCC assists the Board in the succession planning process in respect of 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 systematically 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.

As a result of this succession planning, the Company was confident in appointing Scott Balfour as the President and CEO, upon the retirement of the former President and CEO, Chris Huskilson, in March 2018. Mr. Balfour joined Emera in 2012 and took on increasing levels of responsibility with the Company while playing a key role in the Company’s growth, serving as Chief Operating Officer and Chief Financial Officer prior to becoming President and CEO. The Company’s ability to select a successor internally is a testament to the depth of the leadership team and the succession work that has been undertaken. Moreover, the Company had arranged for Mr. Huskilson to give at least 12 months’ notice of his intention to retire, which allowed for a productive and seamless leadership transition.

In 2018, after extensive consultations with employees across all of Emera’s affiliates, the Company developed a new leadership competencies model, which is aligned with our business strategy and connected to our values, as articulated in our Code of Conduct. These leadership competencies will 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 every affiliate. The alignment of all employees to a common set of competencies provides the foundation from which we can 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 overall leadership team with regards 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.

 

44             Emera Inc. — Management Information Circular 2019


MANAGEMENT INFORMATION CIRCULAR

 

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 2018 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 2017 and 2018.

 

      2018    2017

Advisor

 

  

MRCC

work ($)

   Other
work ($) (1)
  

MRCC

work ($)

   Other
work ($)

Hugessen Consulting Inc.

   114,656    Nil    143,757    Nil

Morneau Shepell

   Nil    39,771    Nil    57,124

Mercer (Canada) Ltd.

   Nil    129,000    Nil    98,567
(1)

Mercer (Canada) Ltd. was retained by the Nominating and Corporate Governance Committee in 2018 to review directors’ compensation.

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. from March 29, 2018 onward (“President and CEO”); Chief Operating Officer, Emera Inc. from January 1, 2018 to March 29, 2018;

 

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.;

 

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

 

Christopher Huskilson, President and Chief Executive Officer, Emera Inc., from January 1, 2018 to March 29, 2018 (“Former President and CEO”).

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

In March of 2018, Mr. Balfour was appointed President and CEO of Emera Inc. He continues to serve as Chair of the Boards of Tampa Electric Company and Nova Scotia Power Inc. Under his leadership, Mr. Balfour continued to advance Emera’s safety culture and performance. 2018 was a year of strong financial performance with Emera posting record adjusted earnings per share (up 17 per cent from 2017) and cash flow (up 39 per cent from 2017). He guided the leadership team to perform a comprehensive portfolio optimization review that led to the announced agreement to sell three gas-fired generation facilities in New England. The portfolio work continues and is expected to be completed by the end of 2019. This work has positioned Emera well to funding its capital program which includes 600 megawatts of solar and the modernization of the Big Bend Facility in Florida. Prior to his current role, Mr. Balfour served as Chief Operating Officer and Chief Financial Officer.

Greg Blunden, Chief Financial Officer, Emera Inc.

Since becoming CFO in 2016, Mr. Blunden has demonstrated financial leadership across all of Emera’s diverse operations. In 2018, Mr. Blunden led the development of Emera’s capital investment funding plan and the portfolio optimization plan in support of the Company’s growth initiatives. In addition, he jointly led a number of productivity and efficiency initiatives across Emera’s shared services. Mr. Blunden is a Chartered Professional Accountant and has previously served in a number of finance, business development and strategy roles at Emera and its affiliates.

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

2018 marked Ms. Tower’s first full year leading Emera’s largest affiliate, overseeing Tampa Electric’s business strategy and operations. She had significant accomplishments in 2018 including promoting Tampa Electric’s safety culture through new systems, processes and leadership visibility. In addition, she has advanced significant capital plans such as the 600 megawatt solar construction and the Big Bend modernization project. Ms. Tower is a Fellow Chartered Accountant and has previously served in a number of roles across Emera including Executive Vice President and Chief Financial Officer, President and CEO of Emera Newfoundland and Labrador and Vice President of Customer Operations at Nova Scotia Power Inc.

 

Emera Inc. — Management Information Circular 2019            45


 

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

At the beginning of 2018, Mr. Bennett was appointed President and CEO of Emera Technologies LLC, 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. Solid progress was made in its first year of operations, including developing a formal strategy, establishing strategic partnerships and exploring new opportunities to deliver renewable, safe and always on energy to customers. Mr. Bennett also serves as a director on the boards of Tampa Electric Company, New Mexico Gas Company and Peoples Gas.

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. Mr. Marchand led teams that made very good progress in these critical areas for the Company, including the advancement of Emera’s cybersecurity and data privacy plans, which further increases resiliency across the business.

Christopher Huskilson, Former President and Chief Executive Officer, Emera Inc.

In March 2017, Mr. Huskilson announced his intention to retire after 38 years with Emera and Nova Scotia Power Inc. He worked closely with his successor, Mr. Balfour, during a well-executed 12-month transition period. He retired on March 29, 2018. Throughout 2018, he continued to serve on the Tampa Electric Company and Emera Technologies boards.

The total target compensation for each NEO in 2018 is outlined below, except for the Former President and CEO, whose compensation is discussed in Compensation of Former President and CEO in 2018:

 

Name

 

  

Base    

salary ($)    

 

      

Short-term    
incentive    

at target (%)    

 

      

Short-term    
incentive at    
target ($)     

 

      

Long-term    
incentive    

at target (%)    

 

      

Long-term    
incentive at    
target ($)     

 

      

Total target    
compensation    

($)    

 

 

Scott Balfour

     1,000,000              100              1,000,000              280              2,800,000              4,800,000      

Greg Blunden

     500,000              70              350,000              150              750,000              1,600,000      

Nancy Tower

     600,000              60              360,000              150              900,000              1,860,000      

Robert Bennett(1)

     615,458              60              369,275              125              769,322              1,754,054      

Bruce Marchand

     450,000              60              270,000              145              652,500              1,372,500      

 

(1)

Mr. Bennett is paid in USD. His base salary in 2018 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 = $1.2957 CAD, which is based on the Bank of Canada daily average exchange rate between CAD and USD for 2018.

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 2018 compensation plan design resulted in over half of each NEO’s total target compensation being at risk, with the average for the five NEOs being 70 per cent.

 

 

LOGO

 

46             Emera Inc. — Management Information Circular 2019


MANAGEMENT INFORMATION CIRCULAR

 

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, which 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 fairly compare 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 utility, energy and general industry sectors; and (2) a US group made up of US utility and energy companies. It consists of the following companies:

 

 

  Canadian Comparators

 

  

 

US Comparators

 

   

  Energy & Utility Industry

  Fortis Inc.

  Hydro One Ltd.

  ATCO Ltd.

  TransAlta Corp.

  Enbridge Inc.

  TransCanada Corp.

  Pembina Pipeline Corp.

  Inter Pipeline Ltd.

  AltaGas Ltd.

 

  General Industry

  Rogers Communications Inc.

  Loblaw Companies Ltd.

  Restaurant Brands International LP

  TELUS Corp.

  Potash Corporation of Saskatchewan (1)

  Agrium Inc. (1)

  CGI Group Inc.

  Goldcorp Inc.

  Canadian Tire Corp. Ltd.

  First Quantum Minerals Ltd.

  Teck Resources Ltd.

  

Energy & Utility Industry

Sempra Energy

WEC Energy Group, Inc.

Eversource Energy

DTE Energy Company

CMS Energy Corp.

Ameren Corp.

SCANA Corp.

CenterPoint Energy, Inc.

NiSource Inc.

Alliant Energy Corp.

Pinnacle West Capital Corp.

UGI Corp.

Westar Energy, Inc. (2)

Atmos Energy Corp.

Great Plains Energy Inc. (2)

OGE Energy Corp.

  (1) 

Potash Corporation of Saskatchewan and Agrium Inc. merged in January 2018 to create Nutrien Ltd.

  (2) 

Great Plains Energy Inc. and Westar Energy, Inc. merged in May 2018 to create Evergy, Inc.

This inclusion of US companies reflects that approximately 75 per cent of the Company’s assets are now US-based and approximately 70 per cent of the Company’s revenues came from US operations in 2018. 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 10-year average exchange rate between Canada and the US to smooth out the impact of currency fluctuations.

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 Inc. — Management Information Circular 2019            47


 

LOGO

The MRCC will continue to regularly review the composition of Emera’s comparator group to ensure it continues to reflect the Company’s characteristics and will make adjustments to the comparator group where appropriate.

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 for 2018 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.

 

48             Emera Inc. — Management Information Circular 2019


MANAGEMENT INFORMATION CIRCULAR

 

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 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 all of 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 2017, 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 2018.

With Mr. Balfour assuming the role of President and CEO, the Board approved increases to his base salary, short-term incentive target and long-term incentive target to bring his total target compensation to $4.8 million. 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. The compensation change was effective January 1, 2018, recognizing Mr. Balfour’s efforts and increasing responsibility through the transition period from his role as Chief Operating Officer to President and CEO.

Mr. Huskilson’s 2018 compensation is discussed in Compensation of Former President and CEO in 2018.

Mr. Marchand received an increase to his base salary in light of the increasingly broad scope and complexity of his role and his comparative compensation positioning to market.

The remaining three NEOs did not receive changes to their target compensation in 2018.

The compensation changes from 2017 to 2018 are summarized below. All changes were effective January 1, 2018:

 

    

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

  

Increase from

$685,000 to $1,000,000

   Increase from 90 to 100 per cent    Increase from 175 to
280 per cent
   92   

Increase from

73 per cent to 79 per cent

         

  Greg Blunden

   No change    No change    No change    No change   

No change

(69 per cent)

           

  Nancy Tower

   No change    No change    No change    No change   

No change

(68 per cent)

         

  Robert Bennett

   No change    No change    No change    No change   

No change

(65 per cent)

           

  Bruce Marchand

   Increase from $405,000 to $450,000    No change    No change    11.1   

No change

(67 per cent)

As a result of the changes, the variable or at-risk component of the NEOs’ compensation averaged 70 per cent in 2018. The changes made to the compensation of the respective NEOs in 2018 are also reflected in the NEO Summary Compensation Table.

Compensation of Former President and CEO in 2018

The benchmarking reviews conducted at the end of 2017 indicated that the compensation of some of the NEOs, including the Former President and CEO, were below the targeted percentiles when compared against companies in the Company’s comparator group. In light of Mr. Huskilson’s performance and his market positioning, the Board increased his total target compensation from $6.0 million to $6.6 million at the beginning of 2018.

As discussed in last year’s Management Information Circular, recognizing that Mr. Huskilson was retiring at the end of March 2018, the Board approved an arrangement in 2017 with Mr. Huskilson under which he was not eligible to receive a short-term incentive payout for the 2018 performance year and did not receive a grant of stock options or PSUs in 2018. In lieu of receiving a short-term incentive payout or long-term incentive grants, Mr. Huskilson received:

 

   

a lump sum payment on retirement equal to one-quarter of the target value of (a) his short-term incentive, and (b) the stock option and PSU grants that would have been granted to him in 2018. The one-quarter proration reflected the amount of time Mr. Huskilson was employed with Emera in 2018; and

   

the vesting of the second, third and fourth quarters of Mr. Huskilson’s 2017 stock option grant was accelerated by one year upon his retirement, consistent with the terms of his employment agreement. Under the Stock Option Plan terms, those quarters would vest in February 2019, February 2020 and February 2021, respectively. The arrangement accelerated the vesting to March 2018, February 2019 and February 2020, respectively. Mr. Huskilson has until June 30, 2020 to exercise his stock options.

The arrangement was conditional upon him remaining as CEO through transition to his March 2018 retirement date, which he did. This arrangement reflects that Mr. Huskilson was not going to be employed during the majority of the 2018 short- and long-term incentive plan performance periods, which minimized his ability to contribute toward the achievement of the incentive plans’ performance objectives. Mr. Huskilson did not receive any severance or retirement award upon retiring from the Company.

 

Emera Inc. — Management Information Circular 2019            49


 

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.

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.

All NEOs have their short-term incentive payouts calculated based on results achieved through the scorecard.

2018 Short-Term Incentive Results

2018 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 2018. It was used to determine the short-term incentive payout for 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 2018.

 

  Emera Corporate Objective    

 

  

Weighting (%)  

 

  

Threshold ($)  

 

  

Target ($)  

 

  

Stretch ($)  

 

  

 

Actual  

Result ($)  

 

  

 

Percentage  

Payout (%) (1)  

 

 
           

  Cash From Operations (2)

 

  

40  

 

  

1,090M  

 

  

1,363M  

 

  

1,636M  

 

  

1,619M  

 

    

 

77.6  

 

 

 

           

  Net Income After Tax (2)

 

  

40  

 

  

521M  

 

  

613M  

 

  

705M  

 

  

640M  

 

    

 

51.7  

 

 

 

       
  Safety    10     

Objectives included:

•  Affiliates implement a safety/audit compliance program;

•  Proactive Incident Rate (PAIR) >= 400;

•  Affiliates complete an external/third-party baseline safety program/system audit;

•  Affiliates to complete external “issue audits”; specifically, contractor safety program and hazardous/critical tasks procedures; and

•  Completion of safety culture survey across all affiliates.

  

Stretch  

Achieved  

     20    
       

  People, Environment &

  Corporate Social Responsibility

   10     

Objectives included:

•  Formalize annual Corporate Social Responsibility (CSR) reporting framework;

•  Environmental audit program completed without findings of major risk;

•  Environmental critical targets are 100 per cent complete;

•  Approval of revised leadership competencies for incorporation into performance management systems and leadership assessment process for 2019 implementation;

•  Affiliates design and deliver regulatory stakeholder engagement plan; and

•  Corporately develop Community Investment and Economic Development Strategy including Emera’s scholarship programs.

  

Between Target  

and Stretch   Achieved  

     17.5    
    

 

100  

 

            

 

 

 

 

Total: 166.8  

 

 

 

 

 

(1)

Percentage payouts, below or above target for financial measures, are prorated 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 2018 is discussed in the footnotes in the following table.

Based on the objectives of the People, Environment and Corporate Social Responsibility measure, the Company achieved full stretch performance; however, management proposed a reduction of the payout from 20 per cent to 17.5 per cent to better reflect the overall performance in this area in 2018. The MRCC and Board agreed with this recommendation.

 

50             Emera Inc. — Management Information Circular 2019


MANAGEMENT INFORMATION CIRCULAR

 

The cash from operations and net income after tax results exceeded the target level of performance, with the Company delivering record results on both measures.

The Safety measure achieved the stretch level of performance, with the Company meeting all the required safety objectives. The Company achieved between target and stretch on the People, Environment & Corporate Social Responsibility measure, delivering on almost all the objectives set at the beginning of 2018.

Based on the Company’s achievements against the corporate objectives in the Scorecard, the overall Scorecard result was 166.8 per cent of target.

The cash from operations and net income after tax figures that are shown in the Scorecard are adjusted from the Company’s reported figures. The Company adjusts the reported figures for specific items the Company believes are significant, but not reflective of underlying operations in the period. The table below shows the reconciliation between the reported and adjusted figures used in the Scorecard:

 

Cash From Operations Reconciliation (in millions $)

 

    

 

2018

 

 

 

Reported cash flow before working capital

     1,806  

Deduct: Change in working capital

 

    

 

(116

 

 

Operating cash

     1,690  

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

 

    

 

(71

 

 

Adjusted cash from operations

 

    

 

1,619

 

 

 

Net Income After Tax Reconciliation (in millions $)

 

    

 

2018

 

 

 

Reported net income after tax

     710  

Deduct: After-tax mark-to-market gain

     (39

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

 

    

 

(31

 

 

Adjusted net income after tax

     640  

The table below shows how Emera’s cash from operations and net income after tax has trended from 2013 to 2018 (the amounts shown are as at December 31 of each year).

 

 

     2014          2015(3)       2016 (3)       2017 (4)       2018 (5)  

Cash From Operations ($) (1)

   763M      726M       878M       1,218M       1,619M  

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

 

  

319M

 

    

 

330M

 

 

 

   

 

302M

 

 

 

   

 

535M

 

 

 

   

 

640M

 

 

 

(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 2015 and 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 (as described in footnote 1 in A Letter from the Management Resources and Compensation Committee to Our Shareholders) 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.

Cash from operations and net income after tax have trended upwards over the last five years. Scorecard payouts on average over the same period have been 33 per cent over target.

 

Emera Inc. — Management Information Circular 2019            51


 

2018 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)

 

  40     262.4M      291.5M      305.5M      293.7M     43.1 
             

 Cash From Operations (1)

 

  5     641.3M      675M      708.8M      710.6M     7.5 

 

 Safety

 

 

20  

 

Objectives included:

•  Implement a safety/audit compliance program;

•  Proactive Incident Rate (PAIR) Index of 1,200;

•  100 per cent of high-potential near misses investigated and mitigated; and

•  Contractor safety program implemented and audited by third party.

  

 

Target  

Achieved  

 

 

20 

 

 People

 

 

10  

 

Objectives included:

•  Implement 135 continuous improvement projects;

•  Have 95 per cent of leaders trained on the new performance management process;

•  Review/revise 100 per cent of vice president/director/manager position requirements (experience and education) to address workforce demographics and leadership readiness; and

•  Develop action plans for the prioritized gaps from the workforce plan.

  

 

Stretch  

Achieved  

 

 

20 

 

 Customer

 

 

15  

 

Objectives included:

•  Complete 12,000 employee hours of volunteer work;

•  Implement the JD Power communications and social media plan;

•  Successfully complete 70 per cent of Power Quality Reliability Index; and

•  Successfully complete 70 per cent of service level and participation index.

  

 

Stretch  

Achieved  

 

 

30 

 

 Asset Management

 

 

10  

 

Objectives included:

•  Automated Metering Infrastructure (AMI) brought to Board for approval;

•  90 per cent communications network deployment for AMI;

•  Big Bend modernization project brought for Board approval;

•  Phase 1 solar in service; and

•  Solar integration and storage studies complete.

  

 

Stretch  

Achieved  

 

 

20 

         
   

100  

 

          

Total: 140.6 

 

  (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 prorated on a scale between each level of performance (50 per cent for threshold, 100 per cent for target and capped at 150 per cent for stretch).

 

52             Emera Inc. — Management Information Circular 2019


MANAGEMENT INFORMATION CIRCULAR

 

2018 Emera Technologies Scorecard

The scorecard for Emera Technologies LLC (“Emera Technologies Corporate Scorecard”) was developed by management and approved by the Emera Technologies Board of Directors. It was used to determine the short-term incentive payout for Mr. Bennett. Part of the Emera Technologies Corporate Scorecard was based on the Emera Corporate Scorecard; the Emera cash from operations, net income after tax and safety metrics were incorporated into the Emera Technologies Corporate Scorecard and represented 50 per cent of the Scorecard weighting. The remaining 50 per cent consisted of metrics specific to Emera Technologies, involving asset management, people and customer objectives. The Scorecard is shown below:

 

             

Emera Technologies

Corporate Objective

  Weighting (%)     Threshold ($)      Target ($)      Stretch ($)     

Actual  

Result ($)  

 

Percentage  

Payout (%) (2)  

             
 Emera Inc. Cash From  Operations (1)   20      1,090M      1,363M      1,636M      1,619M     38.8  
             
 Emera Inc. Net  Income After  Tax (1)   20      521M      613M      705M      640M     25.9  

 

 Emera Inc. Safety

 

 

10   

 

Objectives included:

•  Affiliates implement a safety/audit compliance program;

•  Proactive Incident Rate (PAIR) >= 400;

•  Affiliates complete an external/third-party baseline safety program/system audit;

•  Affiliates to complete external “issue audits”; specifically, contractor safety program and hazardous/critical tasks procedures; and

•  Completion of safety culture survey across all affiliates.

  

 

Stretch  

Achieved  

 

 

20  

 

 Asset Management

 

 

20   

 

Objectives included:

•  Developing a new technology and testing it in a university research lab setting to demonstrate its viability.

  

 

Stretch  

Achieved  

 

 

40  

 

 People

 

 

20   

 

Objectives included:

•  Establish strategic relationships; and

•  Secure a memorandum of understanding with one strategic partner.

  

 

Target  

Achieved  

 

 

20  

 

 Customer

 

 

10   

 

Objectives included:

•  Business model and business case studies complete and propose a viable path to commercialization; and

•  Create/assemble an intellectual property portfolio as part of path to commercialization.

  

 

Stretch  

Achieved  

 

 

20  

         
   

100   

 

          

Total: 164.7  

 

  (1)

See footnote (2) in the Emera Corporate Scorecard on page 50.

  (2)

Percentage payouts, below or above target for financial measures, are prorated 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).

 

Emera Inc. — Management Information Circular 2019            53


 

Long-Term Incentive Program

There are two primary components of long-term incentive compensation for senior management, including the NEOs: the Performance Share Unit Plan (the “PSU Plan”) and the Senior Management Stock Option Plan (the “Stock Option Plan”). The MRCC is responsible for granting PSUs and stock options.

The number of PSUs 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 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 takes into account previous grants and looks at a three-year history of total compensation each year before approving any new stock option and PSU 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 2018, PSUs made up 75 per cent of the target long-term incentive compensatory value, and stock options made up the remaining 25 per cent for all NEOs, with the exception of the Former President and CEO, whose compensation is discussed in Compensation of Former President and CEO in 2018.

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

Performance Share Unit Plan

The PSU Plan is designed to retain and incent 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, 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. If targets are exceeded, the performance factor may increase the payout by up to two times.

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

 

54             Emera Inc. — Management Information Circular 2019


MANAGEMENT INFORMATION CIRCULAR

 

Performance Share Unit Plan Results

The 2016 PSU grant had a performance period of January 1, 2016 to December 31, 2018. When the Company was setting the performance metrics for the 2016 PSU grant, it considered the significant impact the acquisition of TECO Energy, Inc. could have on earnings. Since the timing of the closing could heavily influence EPS in 2016, the Company removed EPS as a performance metric for the 2016 grant and used only one performance metric – relative TSR. The Company returned to using multiple metrics in 2017 and 2018.

The performance factor for the 2016 PSU grant was based on Emera’s average three-year TSR relative to the average three-year TSR of the S&P/TSX Capped Utilities Index as illustrated in the table below.

 

Relative annual return to S&P/TSX Capped Utilities Index

 

  

Performance Factor        

 

 

Less than -2.5%

     0        

-2.5%

     0.5        

2.5%

     1.0        

10% or more

     1.5        

The performance factor was interpolated on the basis of the actual relative returns. All annual average returns or percentages over the three-year performance period were determined on a compounded basis.

The following table shows the performance factor results for the three-year period from January 1, 2016 to December 31, 2018:

 

     

Relative Total Shareholder Return

 

 
      Emera TSR      S&P/TSX Capped
Utilities Index TSR
 

Year – 2016

     9.6%        17.6%  

Year – 2017

     8.3%        10.6%  

Year – 2018

     -1.8%        -7.7%  

Average annual compounded return

     5.24%        6.28%  

Emera’s relative TSR

              -1.04%          

Resulting performance factor

              0.65                   

The overall performance factor applied to the 2016 PSU grant was 0.65, based on Emera’s TSR underperforming the TSR of the S&P/TSX Capped Utilities Index by one per cent on an annual basis over the three-year performance period. The total payout for all PSU Plan participants in respect of the 2016 PSU grant was approximately $6.2 million. The payout for each participant was 75 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.

2018 PSU Grant Performance Metrics

Following the acquisition of TECO Energy, Inc., the Company reviewed the measures that most appropriately reflect the long-term success of Emera. The Company’s long-term focus is on cash generation, particularly in light of the impact the acquisition had on the Company’s balance sheet and the importance of de-leveraging. Accordingly, the Company used the following two equally weighted metrics for the 2018 PSU grant:

1.     EPS growth, which continues to be a fundamental measure of the bottom line 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.

The combination of the two metrics will effectively measure Emera’s long-term value creation by balancing both profitability and growth. The Company also used these two metrics for the 2017 PSU grant.

In addition to the above metrics, the Company is using TSR as a modifier, where the performance factor resulting from the two metrics can be increased or decreased 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 is positioned in the top quartile of performance of companies in the S&P/TSX Capped Utilities Index, the performance factor will be increased by 25 per cent; if Emera’s TSR is positioned in the bottom quartile, the performance factor will be reduced by 25 per cent. There is no adjustment if Emera’s TSR is in the second or third quartile. This allows the Company to focus on its specific business objectives, but still manage Shareholder expectations by adjusting the results for relative performance.

The performance factor can range from 0 per cent to 200 per cent. The maximum performance factor is 200 per cent, even with the impact of the performance modifier. If the performance metric results multiplied by the modifier exceed 200 per cent, the performance factor will be capped at 200 per cent.

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 in the top quartile while still being negative. This provision helps ensure payouts are reasonable when Shareholders experience low returns on their investment.

The performance period for PSUs granted in 2018 is from January 1, 2018 to December 31, 2020 and the table below shows the performance factor levels:

 

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

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

   4%        8%     12%    

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

   4%        10%     16%    

 

Emera Inc. — Management Information Circular 2019            55


 

 

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 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 2018 Annual Report respecting risks and assumptions relevant to Emera’s determination of performance targets for compensation purposes.

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 2018 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.

For the 2018 stock option grant, the Black-Scholes valuation resulted in a value ratio ranging from 1.8 per cent to 6.8 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 2018 was $3.99, which was 10 per cent of the closing Emera common share price of $39.93 on February 13, 2018, the day immediately preceding the grant date. The share price of $39.93 is also the exercise price for the 2018 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 24 months following the option holder’s 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. 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. Please see Termination and Change of Control Benefits for the NEOs’ entitlements on retirement. In 2018, the Company made some changes to how stock options are treated on departure, which take effect in 2019. For a description of these changes, please see Changes to the Long-term Incentive Plans.

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 5.02 per cent of the weighted average total issued and outstanding common shares of the Company in 2018.

There have been 5,183,515 common shares issued under the Stock Option Plan since its inception, which represents approximately 2.22 per cent of the weighted average total issued and outstanding common shares of the Company in 2018. There are 4,225,575 common shares issuable under actual grants of options, which represent approximately 1.81 per cent of the weighted average total issued and outstanding common shares of the Company in 2018 and, of that amount, 2,546,250 are vested and 1,679,325 are unvested.

The Board of Directors of the Company may amend or discontinue the Stock Option Plan by resolution at any time; 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.

 

56             Emera Inc. — Management Information Circular 2019


MANAGEMENT INFORMATION CIRCULAR

 

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.

 

     

2018 (%)

 

  

2017 (%)

 

  

2016 (%)    

 

Dilution

        

(number of options outstanding, divided by number of shares outstanding)

   1.81

 

   1.71

 

   1.70

 

Burn Rate

        

(number of options granted in a fiscal year, minus expired options, divided by the number of shares outstanding)

   0.26    0.39    0.36

Overhang

        

(shares available for issuance, plus options outstanding, divided by the number of shares outstanding)

   2.80    3.06    3.88

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.

Changes to the Long-term Incentive Plans

In 2018, the Company, with the assistance of Mercer, conducted a review of executive entitlements under various departure scenarios to determine how Emera compared to general market practice and to determine how the Company’s long-term incentive plans could be structured to assist in workforce planning and retention. Ensuring our long-term incentive plans are retentive will become increasingly important going forward as many of the Company’s newer executives are in a defined contribution pension plan. Defined contribution pension plans tend to be less retentive than defined benefit pension plans and typically result in less predictable retirement dates.

As a result of the review, the Company made the following changes to the Performance Share Unit Plan and Senior Management Stock Option Plan, which more closely align the plans with market practice and are expected to lead to more predictable succession planning for the Company, without adding any materials costs:

 

   

On retirement, any unvested PSUs and stock options will be eligible to continue to vest for 24 months from the participant’s retirement date, provided the participant is subject to certain pre-determined restrictive covenants and is not being paid any severance amounts as part of the participant’s departure. Any PSUs that vest post-retirement will continue to be subject to the applicable performance conditions. This change does not impact the NEOs, as they have contractual provisions that provided for the same treatment.

   

The definition of “retirement” was standardized to apply a consistent definition for all long-term incentive recipients, irrespective of the pension plan in which they participate, to allow for more consistent treatment.

   

In the event of the death of a long-term incentive recipient, any outstanding PSUs continue to be prorated but will be paid out immediately following death assuming a performance factor of 1.0. Any stock options that would have vested within 12 months from the date of the participant’s death will vest immediately and the participant’s estate will have six months to exercise such options. This allows for timelier settling of estates in the event of a participant’s death.

   

The exercise window for vested options was shortened from six months to 60 days for executives who resign from the Company or who are terminated for cause; any options that have not vested continue to be forfeit upon a resignation or termination for cause.

   

The change in control provisions of both plans were updated to define the events that constitute ‘good reason’ under the second trigger of the double-trigger change in control provisions. The period during which executives can exercise the second trigger is 24 months following a change in control, which is consistent with market practice.

As part of the review, the Company also revised the restrictive covenants and termination provisions in the Company’s executive contracts. The above changes take effect with the 2019 long-term incentive grants, and the updated executive contracts will be implemented going forward.

 

Emera Inc. — Management Information Circular 2019            57


 

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, 2013 to December 31, 2018

 

LOGO

 

 

    As at December 31

 

    

 

2013 ($)

 

 

 

    

 

2014 ($)

 

 

 

    

 

2015 ($)

 

 

 

    

 

2016 ($)

 

 

 

    

 

2017 ($)

 

 

 

    

 

2018 ($)

 

 

 

 

  Emera   

 

 

 

100.00 

 

 

  

 

 

 

131.92 

 

 

  

 

 

 

153.49 

 

 

  

 

 

 

168.17 

 

 

  

 

 

 

182.15 

 

 

  

 

 

 

178.88 

 

 

  S&P/TSX Capped Utilities      100.00         116.05         112.01         131.73         145.72         134.51   
   

S&P/TSX Composite

 

    

 

100.00 

 

 

 

    

 

110.55 

 

 

 

    

 

101.36 

 

 

 

    

 

122.73 

 

 

 

    

 

133.89 

 

 

 

    

 

121.99 

 

 

 

As indicated in the chart, Emera has created significant value for its Shareholders over the last five years. Emera’s cumulative TSR for the five-year period from December 31, 2013 to December 31, 2018 was 79 per cent, which was more than double the 35 per cent return of the S&P/TSX Capped Utilities Index and more than three times the 22 per cent return of the S&P/TSX Composite Index.

While Emera’s TSR declined by 1.8 per cent in 2018, it was less than the declines of the S&P/TSX Capped Utilities Index (7.7 per cent) and S&P/TSX Composite Index (8.9 per cent).

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 2018, 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).

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, 2018) but started at a different beginning period, from January 1, 2009 to January 1, 2018. 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.

 

58             Emera Inc. — Management Information Circular 2019


MANAGEMENT INFORMATION CIRCULAR

 

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, 2018 (3)
  Measurement Period   Realized /Realizable
Value of $100
Target
Pay Awarded to
CEO (3)
  Value of $100
Shareholder
Investment as of
Dec. 31, 2018 (4)
  Difference
2009    $1,882,212    $6,256,036   Jan. 1, 2009 - Dec. 31, 2018   $332   $305   -$27
2010    $2,062,572    $6,038,441   Jan. 1, 2010 - Dec. 31, 2018   $293   $258   -$35
2011    $2,470,109    $2,707,224   Jan. 1, 2011 - Dec. 31, 2018   $110   $197   $87
2012    $2,474,995    $4,157,224   Jan. 1, 2012 - Dec. 31, 2018   $168   $179   $12
2013    $3,573,704    $7,164,064   Jan. 1, 2013 - Dec. 31, 2018   $200   $164   -$36
2014    $3,587,500    $8,057,461   Jan. 1, 2014 - Dec. 31, 2018   $225   $179   -$46
2015    $3,762,500    $3,818,021   Jan. 1, 2015 - Dec. 31, 2018   $101   $136   $34
2016    $4,800,000    $3,250,000   Jan. 1, 2016 - Dec. 31, 2018   $68   $117   $49
2017    $6,000,000    $3,963,434   Jan. 1, 2017 - Dec. 31, 2018   $66   $106   $40
2018    $4,800,000    $5,345,340   Jan. 1, 2018 - Dec. 31, 2018   $111   $98   -$13
              Average   $167   $174   $6

 

  (1)

The lookback table shows the compensation of the Former President and CEO, Chris Huskilson, for 2009 to 2017, and the compensation of the President and CEO, Scott Balfour, for 2018.

  (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, 2018.

  (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 close 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 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 Emera’s TSR relative to the S&P/TSX Capped Utilities Index. 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 2014, 2015 and 2016, 101 per cent for the period ending in 2017, and 65 per cent for the period ending in 2018. The general trend shows performance factors at or above 100 per cent in periods where Emera outperforms the S&P/TSX Capped Utilities Index, and below 100 per cent in periods where the Company underperforms the Index, indicating an alignment between executive and Shareholder interests.

The total annual salary, short-term incentive and long-term PSU payouts in 2018 for the six NEOs totalled $11.4 million, which represents 1.6 per cent of the Company’s net earnings applicable to common shares of $710 million or 1.7 per cent of the Company’s adjusted net earnings applicable to common shares of $671 million, for the period ended December 31, 2018. The MRCC is comfortable that the payout totals for 2018 are reasonable in light of 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 (please see footnote 1 in A Letter from the Management Resources and Compensation Committee to Our Shareholders).

 

Emera Inc. — Management Information Circular 2019            59


 

NEO Summary Compensation Table

 

                                 Non-equity                       
          incentive plan         
          compensation         

    Name and principal position

 

  

Year

 

    

Salary
($)(1)

 

    

Share-based
awards ($) (2)

 

    

Option-based
awards ($)
(3)

 

    

Annual incentive
plans
($)
(4)

 

    

Pension
value
($)
(5)

 

    

All other
compensation
($)
(6)(7)

 

    

Total    
compensation    
($)
(8)     

 

 

    Scott Balfour

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

    President and Chief Executive

     2017        726,920        899,073        299,676        472,239        194,000        31,730        2,623,638      

    Officer

     2016        547,115        721,818        240,702        462,000        188,000        31,891        2,191,526      

    Christopher Huskilson

     2018        321,538        -        -        -        -        1,455,981        1,777,519      

    Former President and Chief

    Executive Officer

     2017        1,095,769        1,899,773        1,900,208        842,600        -        23,592        5,761,942      

    (retired March 29, 2018)

    

 

2016

 

 

 

    

 

995,192

 

 

 

    

 

1,400,127

 

 

 

    

 

1,399,860

 

 

 

    

 

1,200,000

 

 

 

    

 

-

 

 

 

    

 

24,210

 

 

 

    

 

5,019,389    

 

 

 

    Greg Blunden

     2018        500,000        562,468        187,530        583,800        273,000        25,318        2,132,116      

    Chief Financial Officer

     2017        462,328        506,412        168,596        250,227        91,000        26,082        1,504,645      
       2016        379,615        252,933        84,546        246,000        74,000        25,402        1,062,496      

    Nancy Tower

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

    President & Chief Executive

    Officer, Tampa Electric Company

     2017        531,630        596,142        198,880        246,269        322,000        26,247        1,921,168      
     2016        475,000        445,434        148,302        342,000        193,000        27,672        1,631,408      
                 

    Robert Bennett

     2018        615,458        577,156        167,580        608,195        (26,000)        163,271        2,105,660      

    President & Chief Executive

    Officer, Emera Technologies Ltd.

     2017        616,835        578,136        164,076        413,357        234,000        163,624        2,170,028      
     2016        625,266        590,112        148,302        453,082        55,000        207,052        2,078,814      
                 

    Bruce Marchand

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

    Chief Legal & Compliance Officer

     2017        404,788        440,341        146,900        186,138        126,000        16,644        1,320,811      
       2016        398,077        359,988        90,090        288,000        125,000        17,545        1,278,700      

 

  (1)

The figure shown represents actual base earnings paid in 2018.

  (2)

The figure shown is the value of PSU grants as of the effective grant date. The grant value of PSUs granted in 2018 was based on the average 50 trading-day closing share price up to December 31, 2017 ($48.14). The 50-day share price average is used for PSU 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 the stock options granted to the NEOs in 2018 was determined to be equal to 10 per cent of the February 13, 2018 closing share price of $39.93 or $3.99 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 2018 resulted in a value ratio of 1.8 per cent to 6.8 per cent, using an estimated dividend yield of 4.7 per cent, and a risk-free interest rate of 1.98 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 9.0 per cent to 16.2 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 2018, which led to fewer options being granted than if the floor had not been applied.

  (4)

In 2018, Mr. Balfour, Mr. Blunden and Mr. Marchand participated in the Emera Corporate Scorecard, which had a result of 166.8 per cent. Ms. Tower participated in the Tampa Electric Corporate Scorecard, which had a result of 140.6 per cent, and Mr. Bennett participated in the Emera Technologies Scorecard, which had a result of 164.7 per cent. The Short-Term Incentive Plan and the 2018 results are described in greater detail in Short-Term Incentive Plan. The figures shown reflect amounts earned in the 2018 performance year and paid in 2019. Mr. Blunden and Ms. Tower each elected to receive 100 per cent of their short-term incentive payout in the form of DSUs. Mr. Balfour elected to receive 50 per cent of his payout in DSUs and Mr. Marchand elected to receive 25 per cent of his payout in DSUs.

  (5)

Mr. Huskilson’s pension is capped and he has reached his maximum years of credited service. Further information concerning pension values can be found in Pension Plan Benefits.

  (6)

All other compensation in 2018 consists of: for Mr. Balfour, a cash perquisite allowance of $29,692 and other taxable benefits; for Mr. Blunden, a cash perquisite allowance of $20,000 and other taxable benefits; and for Mr. Marchand, a cash perquisite allowance of $12,000 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 $20,000, a housing allowance of $120,767, a cost of living allowance of $45,518, a travel allowance of $18,846, $82,659 in taxable benefits associated with her relocation to Tampa, 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 $33,333 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 = $1.2957 CAD, which is based on the Bank of Canada daily average exchange rate between CAD and USD for 2018. Please see Other Executive Benefits for additional details on the items that are included in these all other compensation figures.

  (7)

The all other compensation figure for Mr. Huskilson reflects the arrangement discussed in Compensation of Former President and CEO in 2018. In lieu of receiving a short-term incentive payout or long-term incentive grants in 2018, Mr. Huskilson received a lump sum payment of $1,375,000 on retirement, which was equal to one-quarter of the target value of (a) his short-term incentive, and (b) the stock option and PSU grants that would have been granted to him in 2018. The one-quarter proration reflected the amount of time Mr. Huskilson was employed with Emera in 2018. The all other compensation figure also includes a car allowance of $5,538, a payout of earned but unused vacation up to Mr. Huskilson’s retirement date of $74,038, and other taxable benefits.

  (8)

Mr. Bennett is paid in USD. His base salary was $475,000 USD, his short-term incentive payout was $469,395 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 10-year average exchange rate between USD and CAD ($1.00 USD = $1.13 CAD) at the time of grant, which matches the term of the options. Any USD amounts applicable to Mr. Bennett have been converted to CAD in the table using the exchange rate of $1.00 USD = $1.2957 CAD, which is based on the Bank of Canada daily average exchange rate between CAD and USD for 2018. 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.

 

60             Emera Inc. — Management Information Circular 2019


MANAGEMENT INFORMATION CIRCULAR

 

Outstanding Share-based Awards and Option-based Awards

The following table describes all option-based and share-based awards outstanding as of December 31, 2018 for each NEO:

 

    Option-based awards (1)         Share-based awards  
     (stock options)                    (performance share units (PSUs) 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

    100,000        33.73        4/15/2022        998,000                67,964        2,912,245        2,189,742    
    28,200        34.80        2/12/2023        251,262                   
    34,800        32.35        2/11/2024        395,328                   
    40,400        42.71        2/11/2025        40,400                   
    52,100        46.19        2/17/2026                          
    66,300        45.16        2/14/2027                          
      175,400        39.93        2/13/2028        663,012                                       

  Chris Huskilson

    72,500        32.06        2/15/2021        844,625                46,233        1,981,074        10,377,193    
    97,700        33.35        2/14/2022        1,012,172                   
    337,700        34.80        2/12/2023        3,008,907                   
    353,900        32.35        2/11/2024        4,020,304                   
    286,100        42.71        2/11/2025        286,100                   
    303,000        46.19        2/17/2026                          
      420,400        45.16        2/14/2027                                              

  Greg Blunden

    1,475        32.06        2/15/2021        17,184                24,666        1,056,951        795,560    
    3,950        33.35        2/14/2022        40,922                   
    9,400        34.80        2/12/2023        83,754                   
    11,300        32.35        2/11/2024        128,368                   
    8,700        42.71        2/11/2025        8,700                   
    18,300        46.19        2/17/2026                          
    37,300        45.16        2/14/2027                          
      47,000        39.93        2/13/2028        177,660                                       

  Nancy Tower

    10,600        21.99        2/12/2019        230,232                29,319        1,256,304        3,663,386    
    21,300        23.94        2/16/2020        421,101                   
    16,900        32.06        2/15/2021        196,885                   
    22,800        33.35        2/14/2022        236,208                   
    28,200        34.80        2/12/2023        251,262                   
    29,600        32.35        2/11/2024        336,256                   
    32,400        42.71        2/11/2025        32,400                   
    32,100        46.19        2/17/2026                          
    44,000        45.16        2/14/2027                          
      56,400        39.93        2/13/2028        213,192                                       

  Robert Bennett (6)

    7,050        34.80        2/12/2023        62,816                20,609        1,144,209        2,258,558    
    14,800        32.35        2/11/2024        168,128                   
    32,400        42.71        2/11/2025        32,400                   
    32,100        46.19        2/17/2026                          
    36,300        45.16        2/14/2027                          
      42,000        39.93        2/13/2028        158,760                                       

  Bruce Marchand

    12,000        32.35        2/11/2024        136,320                21,453        919,251        1,121,640    
    19,100        42.71        2/11/2025        19,100                   
    19,500        46.19        2/17/2026                          
    32,500        45.16        2/14/2027                          
      40,900        39.93        2/13/2028        154,602                                       
(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, 2018 closing share price of $43.71.

(3)

Unvested share-based awards include PSU and unvested special DSU grants, and any additional PSUs and DSUs from dividend reinvestment relating to such grants as of December 31, 2018.

(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 2018 ($42.85).

(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 2018 ($42.85).

(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 = $1.2957 CAD, which is based on the Bank of Canada daily average exchange rate between CAD and USD for 2018.

 

Emera Inc. — Management Information Circular 2019            61


 

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 2018 for each NEO:

 

Name

 

  

Option-based awards value
vested during 2018 ($) (1)

 

    

Share-based awards    
(performance share units (PSUs)     
and deferred share units (DSUs))    

value vested during 2018 ($) (2) (3)

 

    

Non-equity incentive plan
compensation – value earned

during the year ($) (4)

 

 

Scott Balfour

     79,866                539,811                1,668,000      

Christopher Huskilson

     812,201                1,528,904                -      

Greg Blunden

     25,934                189,156                583,800      

Nancy Tower

     67,932                384,473                506,160      

Robert Bennett

     67,932                487,505                608,195      

Bruce Marchand

     48,654                201,843                450,360      
(1)

Represents the aggregate dollar value that would have been realized if stock options had been exercised on the applicable vesting (eligibility) date in 2018.

(2)

The value of PSUs vested in 2018 is based on the 2016 PSU grant, which had a three-year performance period from January 1, 2016 to December 31, 2018. 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 2018 ($42.85). The performance factor for the 2016 PSU grant was based on Emera’s total Shareholder return relative to the S&P/TSX Capped Utilities Index. The performance factor result was 0.65. More details on the PSU Plan and results can be found in Performance Share Unit Plan.

(3)

This dollar amount includes the value of dividends equivalents from past special DSU grants that were paid in the form of additional DSUs in 2018, which were calculated using a closing share price for the last 50 trading days of 2018 ($42.85). This amount equaled $481,819 for Mr. Huskilson, $51,355 for Ms. Tower and $55,884 for Mr. Bennett.

(4)

This amount represents the 2018 incentive payouts as disclosed in the NEO Summary Compensation Table.

Aggregate Option Exercise during 2018 and 2018 Option Values

The following table summarizes the number of common shares, if any, each NEO acquired pursuant to the exercise of stock options in 2018, 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, 2018. 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, 2018, which was $43.71.

 

                   Unexercised options at
December 31, 2018
     Value of unexercised in-the-money
options at December 31, 2018
 

Name

 

  

Securities acquired
on exercise (#)

 

    

Aggregate value

realized ($)

 

    

Exercisable (#)

 

    

Unexercisable (#)

 

    

Exercisable ($)

 

    

Unexercisable ($)

 

 

Scott Balfour

     0          0        235,925        261,275        1,674,890        673,112  

Christopher Huskilson

     0          0        1,438,075        433,255        9,100,583        71,525  

Greg Blunden

     0          0        51,125        86,300        276,753        179,835  

Nancy Tower

     11,000          201,410        180,750        113,550        1,696,244        221,292  

Robert Bennett

     0          0        71,275        93,375        255,244        166,860  

Bruce Marchand

     0          0        44,200        79,800        150,645        159,377  

Pension Plan Benefits

Emera has adopted a pension governance 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) and participate on either a defined benefit basis or a defined contribution basis. For 2018, 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.

 

62             Emera Inc. — Management Information Circular 2019


MANAGEMENT INFORMATION CIRCULAR

 

Defined Benefit

The following table shows years of credited service, estimated pension amounts and changes to accrued obligations from January 1, 2018 to December 31, 2018 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

     6.7        106,000        274,000        1,306,000        634,000        527,000        2,467,000  

Christopher Huskilson(4)

     35.0        650,000        650,000        14,796,000               129,000        14,925,000  

Greg Blunden(5)

     1.3        13,000        13,000        287,000        171,000        13,000        471,000  

Nancy Tower

     21.3        267,000        332,000        6,073,000        337,000        (171,000)        6,239,000  

Robert Bennett

     30.7        359,000        410,000        8,542,000        (26,000)        (142,000)        8,374,000  

Bruce Marchand

 

    

 

7.0

 

 

 

    

 

63,000

 

 

 

    

 

95,000

 

 

 

    

 

984,000

 

 

 

    

 

117,000

 

 

 

    

 

137,000

 

 

 

    

 

1,238,000

 

 

 

(1) Ms. Tower, Mr. Bennett and Mr. Marchand were eligible for an immediate pension at year-end, while Mr. Balfour and Mr. Blunden were not 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, 2018.

(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. Huskilson retired on March 29, 2018. The accrued obligation figure at year-end shown for him is the accrued obligation as of his retirement date.

(5) 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 Pension Plan changes that materially affected the above figures in 2018.

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 2018 were driven largely by the change in the discount rate assumption from 3.50 per cent as at December 31, 2017 to 3.83 per cent as at December 31, 2018, as well as interest on the accrued obligation and current service cost. An increase in the discount rate results in a lower obligation, all other things being equal.

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 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 to a maximum of six per cent per annum.

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.

For 2018, 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’s 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 a supplemental employee retirement plan (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.

 

Emera Inc. — Management Information Circular 2019            63


 

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.

In 2011, Mr. Huskilson’s pension amount payable under the Pension Plan and Supplementary Retirement Plan was capped. The limit at future potential retirement dates was determined based on the pension formula and an assumed increase in pensionable earnings of approximately four per cent per year from the 2010 pensionable earnings levels. This limit has reduced the amount that would otherwise be payable under the normal Pension Plan terms. As a result, year-over-year changes of more than four per cent to Mr. Huskilson’s earnings had no impact on his compensatory change component. Mr. Huskilson reached the maximum years of credited service allowable under the Pension Plan (35 years) in 2015 and, therefore, accrued no more credited service in the Pension Plan or Supplementary Retirement Plan in 2018 prior to his retirement.

The compensatory change figure for Mr. Blunden and Ms. Tower includes 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. Ms. Tower and Mr. Blunden 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, and Mr. Huskilson was also not eligible upon his retirement.

Defined Contribution

The following table shows the changes to accumulated value from January 1, 2018 to December 31, 2018 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)

 

  

 

 

 

 

630,000      

 

 

 

 

  

 

 

 

 

62,000    

 

 

 

 

  

 

 

 

 

4,000        

 

 

 

 

  

 

 

 

 

696,000

 

 

 

 

(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 2018. 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 $13,250 each in 2018. In addition, the Company maintains an account for any contributions which would be made in the absence of the Income Tax Act limits, through the Supplementary Retirement Plan. For 2018, the additional Company contribution for Mr. Blunden was $48,514.

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.

 

64             Emera Inc. — Management Information Circular 2019


MANAGEMENT INFORMATION CIRCULAR

 

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 2018.

2018 DSU Plan Allocations

The table below identifies how much of the short-term incentive for 2018 that each NEO elected to allocate to DSUs:

 

 

Name

 

  

Percentage of 2018 annual incentive elected
 to deferred share units (%)

 

    

Dollar amount of 2018 annual incentive
elected to deferred share units ($) (1)

 

 

Scott Balfour

     50        834,000    

Greg Blunden

     100        583,800    

Nancy Tower

     100        506,160    

Robert Bennett

     0        0    

Bruce Marchand

     25        112,590    

 

   
(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.

The Former President and CEO did not receive a short-term incentive payout for 2018.

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. Mr. Huskilson is subject to this one-year post retirement hold period during which he is required to maintain his required ownership level of five times his base salary. His holdings remained above the required level throughout 2018.

Share ownership is calculated based on: (1) the number of Emera shares an executive owns; and (2) DSUs acquired pursuant to the DSU Plan, which are 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 that 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, 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.

 

Emera Inc. — Management Information Circular 2019            65


 

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, 2018 of $43.71. The table does not include the DSUs that will be allocated as part of the 2018 short-term incentive payout, as described in 2018 DSU Plan Allocations.

 

     Required         
   ownership                                  Value of      Total share             Status  
   level as a      Required             Value of      Common      common      and share      Multiple      of share  
   multiple of      ownership        DSUs      DSUs      shares      shares      equivalent       of base      ownership  

Name

 

  

base salary

 

    

level ($)

 

    

held (#)

 

    

held ($)

 

    

held (#)

 

    

held ($)

 

    

ownership ($)

 

    

    salary (1)

 

    

requirements

 

 

Scott Balfour (2)

     5.0        5,000,000        51,103        2,233,712        50,627        2,212,906        4,446,618        4.4          On track  

Christopher Huskilson (3)

     5.0        5,500,000        242,175        10,585,469        146,565        6,406,356        16,991,825        15.4          Met  

Greg Blunden

     3.0        1,500,000        18,566        811,520        944        41,262        852,782        1.7          On track  

Nancy Tower

     3.0        1,800,000        85,493        3,736,899        47,045        2,056,337        5,793,236        9.7          Met  

Robert Bennett (4)

     3.0        1,846,373        52,708        2,303,887        2,594        113,384        2,417,271        5.1          Met  

Bruce Marchand

 

    

 

3.0

 

 

 

    

 

1,350,000

 

 

 

    

 

26,176

 

 

 

    

 

1,144,153

 

 

 

    

 

3,584

 

 

 

    

 

156,657

 

 

 

    

 

1,300,810

 

 

 

    

 

2.9  

 

 

 

    

 

On track

 

 

 

(1)

Based on executive’s respective base salary as of December 31, 2018.

(2)

Mr. Balfour has five years from the date of his appointment as President and CEO (March 29, 2018) to achieve his ownership level.

(3)

Mr. Huskilson is subject to a one-year post retirement hold period.

(4)

Mr. Bennett’s multiple of base salary figure was calculated using the exchange rate of $1.00 USD = $1.2957 CAD, which is based on the Bank of Canada daily average exchange rate between CAD and USD for 2018.

Ms. Tower and Mr. Bennett have met their required ownership level. Mr. Balfour, Mr. Blunden and Mr. Marchand are all on track to reach their required ownership levels.

Mr. Balfour has until the end of 2023 to reach his ownership level as the President and CEO of five times his base salary. The MRCC increased the share ownership requirements for the NEOs in 2016 following a market review of share ownership guidelines. Mr. Blunden and Mr. Marchand achieved their previous share ownership targets within the required time frame and they both have until the end of 2021 to reach the ownership level of three times their respective base salaries. 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.

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 $8,000 per year, and the Company will match 20 per cent of the first $3,000 in contributions and 10 per cent of any contributions between $3,000 and $8,000. 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 1,046,754 common shares that remain available for issuance under the Employee Common Share Purchase Plan, which represents approximately 0.4 per cent of the weighted average total issued and outstanding common shares of the Company in 2018.

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.

 

      2018 (%)      2017 (%)      2016 (%)  

Burn Rate

        

(number of common shares granted in a fiscal year,

divided by the number of shares outstanding)

     0.10        0.08        0.09  

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.

 

66             Emera Inc. — Management Information Circular 2019


MANAGEMENT INFORMATION CIRCULAR

 

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 some cases, the above entitlements are bundled into an annual perquisite allowance, which is paid out in cash in equal bi-weekly instalments over the course of the year.

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 dependents 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.

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, 2018.

 

          Cash
severance 
     Short-term
incentive
     Performance
share units
     Stock      Continuation
of benefits
(present
        

Name

 

  

Departure scenario (1)

 

  

($)

 

    

($)

 

    

        (PSUs) ($) (2)

 

    

options ($)

 

    

value) ($) (3)

 

    

Total ($)

 

 

Scott Balfour

   Resignation                                          
   Termination for Cause                                          
   Termination without Cause      2,000,000        2,000,000        1,283,264               5,089        5,288,353  
   Control Change      2,000,000        2,000,000        2,912,245        673,112        5,089        7,590,446  
     Retirement                                          

Greg Blunden

   Resignation                                          
   Termination for Cause                                          
   Termination without Cause      500,000        350,000        528,345               4,637        1,382,982  
   Control Change      500,000        350,000        528,345               4,637        1,382,982  
     Retirement                                          

Nancy Tower

   Resignation                                          
   Termination for Cause                                          
   Termination without Cause      600,000        360,000        625,986               3,405        1,589,391  
   Control Change      600,000        360,000        1,256,304                      2,216,304  
     Retirement                                          

Robert Bennett (4)

   Resignation                                          
   Termination for Cause                                          
   Termination without Cause      615,458        369,275        581,913               3,405        1,570,051  
   Control Change      615,458        369,275        1,144,209                      2,128,942  
     Retirement                                          

Bruce Marchand

   Resignation                                          
   Termination for Cause                                          
   Termination without Cause      675,000        405,000        459,479               3,811        1,543,290  
   Control Change      675,000        405,000        459,479               3,811        1,543,290  
     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 are valued using the average closing share price for the last 50 trading days of 2018 ($42.85).

(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 = $1.2957 CAD, which is based on the Bank of Canada daily average exchange rate between CAD and USD for 2018.

(5)

The former President and CEO, Chris Huskilson, retired in March 2018 and has therefore been excluded from the above table. His entitlements on retirement are outlined in the table below.

 

Emera Inc. — Management Information Circular 2019            67


 

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, 2018.

 

 

Scott Balfour

 

   

Resignation

 

 

All unvested PSUs and stock options are forfeited.

 

   

Terminated
for cause

 

 

All unvested PSUs 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 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, 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 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 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) 26 months from the date of retirement; and (b) 10 years from the original grant date.

 

 

 

Christopher Huskilson

 

   
Retirement  

Mr. Huskilson retired from the Company on March 29, 2018. Information regarding pension entitlement is contained in Pension Plan Benefits. PSUs 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.

 

As discussed in Compensation of Former President and CEO in 2018, recognizing that Mr. Huskilson was retiring at the end of March 2018, the Board approved an arrangement in 2017 with Mr. Huskilson under which he was not eligible to receive a short-term incentive payout for the 2018 performance year and did not receive a grant of stock options or PSUs in 2018. In lieu of receiving a short-term incentive payout or long-term incentive grants, Mr. Huskilson received:

 

•  a lump sum payment on retirement equal to one-quarter of the target value of (a) his short-term incentive, and (b) the stock option and PSU grants that would have been granted to him in 2018. The one-quarter proration reflected the amount of time Mr. Huskilson was employed with Emera in 2018; and

 

•  the vesting of the second, third and fourth quarters of Mr. Huskilson’s 2017 stock option grant was accelerated by one year upon his retirement, consistent with the terms of his employment agreement. Under the Stock Option Plan terms, those quarters would vest in February 2019, February 2020 and February 2021, respectively. The arrangement accelerated the vesting to March 2018, February 2019 and February 2020, respectively. Mr. Huskilson has until June 30, 2020 to exercise his stock options.

 

The arrangement was conditional upon him remaining as CEO through transition to his March 2018 retirement date. This arrangement reflects that Mr. Huskilson was not going to be employed during the majority of the 2018 short- and long-term incentive plan performance periods, which minimized his ability to contribute toward the achievement of the incentive plans’ performance objectives. Mr. Huskilson did not receive any severance or retirement award upon retiring from the Company.

 

 

Greg Blunden

 

   
Resignation  

All unvested PSUs and stock options are forfeited.

 

   

Terminated
for cause

 

  All unvested PSUs 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 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 and there is a substantial reduction in responsibilities or scope of authority, Mr. Blunden may elect, within three months following such substantial reduction in responsibilities or scope of authority, to terminate employment 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 are prorated to the date of termination and paid out assuming a performance factor of 1.0. Unvested stock options are forfeited.

 

   
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 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 are forfeited.

 

 

68             Emera Inc. — Management Information Circular 2019


MANAGEMENT INFORMATION CIRCULAR

 

 

Nancy Tower

 

   
Resignation  

All unvested PSUs and stock options are forfeited.

 

   

Terminated

for cause

 

  All unvested PSUs 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 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 and there is a substantial reduction in responsibilities or scope of authority, Ms. Tower may elect, within three months following such substantial reduction in responsibilities or scope of authority, to terminate employment and receive 12 months’ compensation calculated on the basis of her annual salary and short-term incentive at target. Unvested PSUs are deemed to vest on the termination date. Unvested stock options are forfeited.

 

   
Retirement  

Ms. Tower becomes eligible to retire with an unreduced pension as of March 31, 2019. Information regarding pension entitlement is contained in Pension Plan Benefits. PSUs 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.

 

 

 

Robert Bennett

 

   
Resignation  

All unvested PSUs and stock options are forfeited.

 

   

Terminated

for cause

  All unvested PSUs 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 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 and there is a substantial reduction in responsibilities or scope of authority, Mr. Bennett may elect, within three months following such substantial reduction in responsibilities or scope or authority, to terminate employment and receive 12 months’ compensation calculated on the basis of his annual salary and short-term incentive at target. Unvested PSUs are deemed to vest on the termination date. Unvested stock options are forfeited.

 

   
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 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 and stock options are forfeited.

 

   

Terminated

for cause

 

  All unvested PSUs 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 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 and there is a substantial reduction in responsibilities or scope of authority, Mr. Marchand may elect, within three months following such substantial reduction in responsibilities or scope or authority, to terminate employment and receive 18 months’ compensation calculated on the basis of his annual salary and short-term incentive at target. Health, dental and other such benefits will be continued for up to 12 months. Unvested PSUs are prorated to the date of termination and paid out based on an estimated future value. Unvested stock options are forfeited.
   
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 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.

 

 

Emera Inc. — Management Information Circular 2019            69


 

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, 2018. 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

       4,225,575          39.56          2,290,910  

• Employee Common Share Purchase Plan

       N/A          N/A          1,046,754  

Total

       4,225,575          39.56          3,337,664  

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 at any time in 2018, 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.

 

70             Emera Inc. — Management Information Circular 2019


MANAGEMENT INFORMATION CIRCULAR

 

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.

Independence and Integrity

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.

The Board shall, through its oversight of management, continue to foster an organization which operates in a safe and environmentally responsible manner.

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.

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.

 

Emera Inc. — Management Information Circular 2019            71


 

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.

 

72             Emera Inc. — Management Information Circular 2019


 

 

LOGO  

www.emera.com

EX-99.2 3 d732548dex992.htm EX-99.2 EX-99.2

Exhibit 99.2

 

LOGO


LOGO


WHY INVEST IN EMERA        |        EMERA AT A GLANCE        |        HIGHLIGHTS        |        LETTER FROM THE CHAIR        |        LETTER FROM THE CEO        |        FINANCIAL REVIEW

 

 

WHY INVEST IN EMERA

Customer demand for cleaner, affordable, reliable energy delivered safely is steadily increasing. Through our regulated electricity and gas assets, and exploring innovative solutions for current and future energy needs, Emera is well positioned to meet that demand while delivering sustainable, growing dividends to our shareholders.

 

 

SUPERIOR
SHAREHOLDER
RETURNS

 

       STRONG    
EARNINGS    
     

          GROWING

          DIVIDEND

     

 

          GROWING
        OPERATING
       CASH FLOWS

 

     

           VISIBLE

    GROWTH PLAN

                          

 

Five year annualized

total shareholder return of

12%

compared to 6%

returned by the TSX

    

 

Adjusted earnings

per share CAGR* of

8%

over the last

five years

   

 

Dividend per share CAGR of

10%

over the last

five years

   

 

12%

CAGR in pre-

working capital

operating cash flow

per share over the

last five years

   

 

$6.5B

capital investment plan to drive rate

base growth

through 2021

Capped Utilities Index                 
and 4% returned by                         
the TSX Composite Index     

90%

of earnings derived

   

4–5%

dividend growth

   

5x cash flow

from operations

   

6%

rate base growth

     from regulated     target through 2021     coverage of     through 2021
Representation in      businesses         dividends     driven by Florida
the TSX Composite,                  investments
TSX Capped Utilities,                     
TSX60 and MSCI World Indices      65%         Investment grade credit ratings    
     of earnings from            
     US operations            

All figures in Canadian dollars and as of December 31, 2018 unless otherwise indicated.

* Compound Annual Growth Rate.

 

EMERA 2018 ANNUAL REPORT

1


WHY INVEST IN EMERA        |        EMERA AT A GLANCE        |        HIGHLIGHTS        |        LETTER FROM THE CHAIR        |        LETTER FROM THE CEO        |        FINANCIAL REVIEW

EMERA AT A GLANCE

From our origins as a single electric utility in Nova Scotia, Emera has grown into an energy leader serving customers in Canada, the US and the Caribbean. Our companies include electric and natural gas utilities, natural gas pipelines, energy marketing and trading, and energy services.

 

 

 

Adjusted Revenue*
As of December 31, 2018

 

By Region    By Revenue Type

 

LOGO

* Adjusted revenue is a non-GAAP measure which excludes mark-to-market adjustments.

 

 

 

TAMPA ELECTRIC

Vertically integrated electric utility serving 764,000 customers in West Central Florida.

PEOPLES GAS

Natural gas utility serving 392,000 customers in Florida.

NOVA SCOTIA POWER

Vertically integrated electric utility serving 519,000 customers in Nova Scotia.

NEW MEXICO GAS

Natural gas utility serving 530,000 customers in New Mexico.

All figures as of December 31, 2018 unless otherwise indicated.

EMERA MAINE

Transmission and distribution electric utility serving 159,000 customers in northern and eastern Maine.

EMERA CARIBBEAN

Vertically integrated electric utilities serving 184,000 customers on the islands of Barbados, Grand Bahama, St. Lucia and Dominica.

EMERA ENERGY

Energy marketing and trading, asset management and optimization in Canada and the US.

EMERA NEWFOUNDLAND & LABRADOR

Owns and operates the Maritime Link and manages Emera’s investments in associated projects.

EMERA UTILITY SERVICES

Utility services contractor working in Atlantic Canada and other regions.

EMERA NEW BRUNSWICK

Manages the Brunswick Pipeline, a 145-kilometre natural gas pipeline in New Brunswick.

EMERA TECHNOLOGIES

A start-up company focused on finding ways to deliver renewable energy to customers.

 

 

EMERA 2018 ANNUAL REPORT

2


LOGO

WHY INVEST IN EMERA    |    EMERA AT A GLANCE    |    HIGHLIGHTS    |    LETTER FROM THE CHAIR    |    LETTER FROM THE CEO    |    FINANCIAL REVIEW $32B $6.5BAssets Revenues 2.5M 7.5K Utility Employees customers Full page: We are a leader in the transition to clean, renewable energy with one of the highest percentages of wind integration in Canada. All figures in Canadian dollars and as of December 31, 2018 unless otherwise indicated. EMERA 2018 ANNUAL REPORT


LOGO

WHY INVEST IN EMERA    |    EMERA AT A GLANCE    |    HIGHLIGHTS    |    LETTER FROM THE CHAIR    |    LETTER FROM THE CEO    |    FINANCIAL REVIEW 2018 FINANCIAL HIGHLIGHTS 2018 dividends were $2.88 $1,806M up 7% adjusted EPS, up from operating cash flow to $2.28 from $2.46 in 2017 (before changes in net $2.13 in 2017 working capital), up from $1,297M in 2017 We’re on track to install 600MW of new solar generation in Florida, and we’re advancing plans to increase our solar capacity in the Caribbean. We’re making energy more efficient through initiatives like our LED roadway lighting replacement programs. By deploying smart meters and other innovative tools, we will give our customers more real-time information on energy use. We’re on track to deploy 1.5 million smart meters across our electric utilities by 2022. Full page: In 2018, we put the Maritime Link into service, connecting the island of Newfoundland to the North American energy grid for the first time in history. EMERA 2018 ANNUAL REPORT


WHY INVEST IN EMERA    |    EMERA AT A GLANCE    |    HIGHLIGHTS    |    LETTER FROM THE CHAIR    |    LETTER FROM THE CEO    |    FINANCIAL REVIEW

 

 

 

OPERATIONAL & ESG HIGHLIGHTS        
              
              

 

OPERATIONAL

 

    

 

ENVIRONMENTAL

 

    

 

SAFETY AND

EMPLOYEES

    

 

GOVERNANCE

 

              
              
    

 

    

 

    

 

 
$1.6B      16%      852      Strong
Maritime Link investment placed into service, on time and on budget               reduction in GHG emissions since 2005*               proactive safety reports for every 100 employees               governance
        

 

2018 Governance Gavel Award recipient

              

 

    

 

    

 

    

 

832MW      $1.7B USD      83%     

Consistently ranked in

top five for The Globe and Mail’s Board Games

of renewable capacity installed

     invested in Florida, including 600MW of solar projects and the modernization of the Big Bend plant      employee engagement index based on 2018 survey, higher than industry norm     

 

              

 

$18.1M

 

    

 

    

 

    

Named one of Canada’s

Best 50

invested in our

communities, including a

special $5M contribution

to establish the Emera

& NB Power Research

Centre for Smart Grid

Technologies*

    

 

 

On track to add

6M

new solar panels at Tampa Electric by 2021

    

 

 

Named one of

Canada’s
Top 100 Employers

for 2019

     Corporate Citizens in 2018 (Corporate Knights)
           
    

 

         
    

600MW

of grid connected wind capacity in Nova Scotia – one of the highest wind integrations in Canada

         

* As of December 31, 2017. 2018 number will be available in Emera’s upcoming Sustainability Update in 2019.

 

EMERA 2018 ANNUAL REPORT

5


WHY INVEST IN EMERA    |    EMERA AT A GLANCE    |    HIGHLIGHTS    |    LETTER FROM THE CHAIR    |    LETTER FROM THE CEO    |    FINANCIAL REVIEW

 

 

LETTER FROM THE CHAIR

Emera delivered solid financial and operational results in 2018, as the team remained focused on executing on strategy and delivering results.

 

In difficult capital market conditions and a challenging year for our industry, we ended 2018 with solid adjusted earnings per share and operating cash flows, and an overall competitive total shareholder return. This underscores our ongoing commitment to delivering shareholder value.

After a 12 month transition period, the Board officially appointed Scott Balfour as Emera’s new President and CEO in March of last year. The careful succession plan and focus on continuity of leadership across the business resulted in a smooth transition for the team and the company.

In 2018, the Board worked closely with the leadership team to ensure the right strategy was in place to continue to deliver long-term shareholder value. Core to that work was supporting management’s efforts to strengthen the balance sheet, including adjusting the dividend growth target and pursuing select asset sales. We are confident that these significant decisions are the right steps to allow us to strategically redeploy capital to our strongest performing assets and investments.

We are encouraged by the team’s commitment to safety, and the progress made to strengthen safety culture,

systems and performance. Safety remains a top priority for the Board, and in particular I want to note the tremendous work of our Health, Safety and Environment Committee, which invested significant time in 2018 reviewing performance and overseeing our cross-company efforts to achieve and maintain industry best practices and standards.

We also continued to focus on strong corporate governance, strategic planning and clear guidance and oversight. Across all sectors, we recognize a growing demand from investors for robust corporate accountability and strong environmental, social and governance (ESG) performance. Emera’s work in governance and ESG is being recognized. In 2018, we received the Governance Gavel Award from the Canadian Coalition for Good Governance for excellence in shareholder communications, and we continued to rank in the top five in The Globe and Mail’s Board Games corporate governance report. Emera was named to Canada’s Top 100 Employers list for the first time, was recognized as one of Canada’s Best Employers by Forbes, and was also celebrated by Corporate Knights as one of Canada’s Best 50 Corporate Citizens for our ongoing work on sustainability.

 

 

   

We also continued to focus on strong

corporate governance, strategic planning and clear guidance and oversight.

 

Jackie Sheppard

Chair, Emera Inc. Board of Directors

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EMERA 2018 ANNUAL REPORT

6


  WHY INVEST IN EMERA    EMERA AT A GLANCE      HIGHLIGHTS     LETTER FROM THE CHAIR            LETTER FROM THE CEO            FINANCIAL REVIEW

 

 

 

We are proud of our strong track record of representation of women on both our Board and management teams. More than 30 per cent of our Director Nominees for election at the company’s 2019 annual shareholders’ meeting are female. In 2018, the Board amended its corporate governance practices to make it a requirement that a minimum of 30 per cent of the Board be composed of women.

In 2018, we remained focused on Board succession, making sure we have the right combination of experience and perspective to guide Emera today and into the future. We were pleased to welcome two new Directors, both with exceptional experience at the helms of successful Canadian public companies. Jim Bertram is the former President and CEO and current Chair of Keyera Corp., a leading midstream oil and gas operator. Jochen Tilk is the former Executive Chairman of Nutrien Inc., a global supplier of agricultural products, and the former President and CEO of PotashCorp. Their experience and vast knowledge make Jim and Jochen valuable additions to the Board.

Two valued members of our Board are stepping down in May 2019. Our longest serving Director, Al Edgeworth, will be retiring after 14 years on the Board. His insights into the energy sector have been invaluable and his recent work as Chair of the Health, Safety and Environment Committee has been critical to Emera’s progress in these areas. On behalf of the Board, I thank Al for his exceptional contribution and wish him the very best. I’d also like to acknowledge Jim Eisenhauer, who will be stepping down from the Emera Board but staying within the Emera family. Jim is a well-known business leader in Nova Scotia and

we have benefitted greatly from his expertise in finance, manufacturing and distribution. After eight years on the Emera Board, Jim will be taking up the role of Lead Independent Director on the Nova Scotia Power Board of Directors. We look forward to his continued wise counsel in this new leadership role.

2018 also marked the passing of our former Director, colleague and friend Wayne Leonard. In his time on our Board, Wayne brought important insight drawn from his extensive career in the US energy industry as former Chair and former CEO of Entergy Corporation. We share our condolences with his family and many friends.

I want to thank my fellow Directors for the dedication and focus they bring to the Board table and for their passionate commitment to Emera’s growth and success.

I thank Scott, the leadership team and all employees across the company for the important work they are doing to deliver on strategy and to position Emera for even more success and growth in future.

Thank you to our valued shareholders for your ongoing support that enables Emera to be a leader in our industry, and to create long-term value for our employees, communities and shareholders.

 

LOGO

Jackie Sheppard

Chair, Emera Inc. Board of Directors

 

 

 

 

LOGO    LOGO    LOGO
The team across Emera is committed to collaboration and operational excellence.    From the Caribbean to Atlantic Canada, we’re delivering for customers and building strong relationships.    Our team members are committed to working safely, always.

 

EMERA 2018 ANNUAL REPORT

7


 

  WHY INVEST IN EMERA    EMERA AT A GLANCE      HIGHLIGHTS     LETTER FROM THE CHAIR            LETTER FROM THE CEO            FINANCIAL REVIEW

 

 

LETTER FROM THE CEO

2018 was a big year in the energy industry as the pace of change towards a lower-carbon, customer-centric future continued to accelerate.

 

These are broad and important trends that align well with Emera’s strategy. However, along with our peers, we also faced broader economic and market challenges. Emera has a proven track record of embracing challenges and finding opportunities in an evolving energy landscape, enabling us to deliver the reliable earnings and long-term growth you expect. I’m proud to say we lived up to that commitment again in 2018, advancing our strategy and delivering on our commitments to you, our customers, communities and the environment.

Last year was also a year of transition for our company as I took over as CEO at the end of the first quarter. As I reflect on the year, I’m grateful to the team and proud of what we accomplished. We strengthened our balance sheet, clarified our growth

plans and articulated our funding approach. We focused on investments in renewable and cleaner energy, modernization of aging infrastructure, and customer-focused technologies. Together, the team across the company delivered strong results in 2018 and positioned Emera well for future growth.

DELIVERING SOLID FINANCIAL RESULTS

There is no question we faced some broad challenges in 2018, including the unique impacts of US tax reform on the utilities sector, shifting positioning by credit rating agencies, anticipating and navigating rising interest rates, and changing sentiment within Canadian equity capital markets. These factors put pressure on our business and our share price. To address these challenges, the team took important

actions, including adjusting our dividend growth rate, developing and executing on a funding plan to minimize the need for new equity to finance our strong organic growth, and mapping out a $6.5 billion growth plan over the next three years.

While responding to those challenges and positioning Emera for future growth, our portfolio of businesses delivered solid financial results in 2018. Adjusted earnings per share (EPS) increased by 17 per cent year-over-year to $2.88. When normalized for the one-time impact of a state-level tax benefit in 2018, adjusted EPS was up 13 per cent to $2.78. We also delivered strong operating cash flow, before changes in net working capital, of $1.8 billion, a 39 per cent increase over 2017. These results were driven by strong growth in our Florida utilities, consistent growth

 

 

 

Together, the team across the company delivered strong results in 2018 and positioned Emera well for future growth.

 

   LOGO

Scott Balfour

President and Chief Executive Officer, Emera

 

EMERA 2018 ANNUAL REPORT

8


  WHY INVEST IN EMERA    EMERA AT A GLANCE      HIGHLIGHTS     LETTER FROM THE CHAIR            LETTER FROM THE CEO            FINANCIAL REVIEW

 

 

 

from our other regulated utilities and very strong performance from Emera Energy as it capitalized on favourable market conditions.

Given the changes and challenges outlined above, Emera’s share price was not where we wanted it to be for much of 2018. For context, our share price was $46.98 at the close of 2017, and we did not see that level again in 2018. In fact, we saw a low of $38.08 in early October. However, I believe the clarity we provided to the market on our capital allocation and funding plans, assisted by positive macro factors, contributed to a turnaround, with our share price ending 2018 at $43.71.

Yet despite the turnaround, Emera’s absolute share price and TSR performance for the full year was negative. Equity capital market conditions were challenging across most sectors and for almost all companies in our sector. It is notable, however, that on a relative basis, Emera’s performance in the market was strong. For the year, we outperformed the TSX Capped

Utilities Index, including all but three companies within the index. We also outperformed the broader TSX Composite Index and the S&P 500 in 2018. Over the last five years, we have similarly outperformed the TSX and Utilities Indexes.

DELIVERING GROWTH

We’re excited about the $6.5 billion in growth opportunities we have in front of us over the next three years, focused on investments in renewable and clean energy, the modernization of aging infrastructure, and customer-focused technologies. To deliver this growth, last year we shared details of our funding plan outlining our increased focus on internal sources of funding instead of raising large amounts of new equity from the market, strengthening our balance sheet and making us more independent of variable market conditions.

In August, we adjusted our dividend growth target to 4-5 per cent through to 2021. We see this level of growth as both competitive and more sustainable, allowing us to

reinvest more in our business while still delivering long-term value for shareholders.

In 2018, we also began our work on optimizing our portfolio to best position us for future growth. In November, we announced the sale of our natural gas generating facilities in New England for $590 million USD. We are advancing our portfolio evaluation, and we expect this work to be complete by the end of 2019.

DELIVERING FOR OUR CUSTOMERS

The energy industry continued to change at an unprecedented rate with shifting customer expectations, increasingly complex regulatory environments and continued demand for cleaner, affordable and reliable energy.

In 2018, we completed construction on two large solar projects, totalling 145MW, at Tampa Electric. This is part of an $850 million USD investment to install 600MW of new solar generation in Florida. In the first few months of 2019, over 2.3 million solar panels were installed over multiple

 

 

 

 

Total Shareholder Return

  

Five Year Annualized Total Shareholder Return

(2014-2018)

LOGO    LOGO

 

EMERA 2018 ANNUAL REPORT

9


  WHY INVEST IN EMERA    EMERA AT A GLANCE      HIGHLIGHTS     LETTER FROM THE CHAIR            LETTER FROM THE CEO            FINANCIAL REVIEW

 

 

 

sites, representing an additional 230MW placed into service. Once this phase of our solar program is complete, seven per cent of Tampa Electric’s energy generation will come from the sun – a tremendous shift to cleaner energy for customers in Florida.

The modernization of the Big Bend facility is another key part of our transformation work at Tampa Electric. This $850 million USD investment will increase efficiency and reduce emissions by upgrading one coal unit to high efficiency natural gas generation and retiring a second unit early. This project will save customers $750 million USD on a net present value basis, reduce carbon intensity and improve the safety of this 50-year-old facility. The modernized plant will also provide a reliable source of baseload energy that can support even more solar development, contributing to a cleaner energy future.

The Maritime Link was placed into service in 2018. This important mega-project enables energy flow between Newfoundland and Labrador and mainland North America for the first time in history and creates a new energy loop in Atlantic Canada. We are proud of this project that fundamentally changes the future of energy in the region and beyond.

We also made good progress on our $500 million investment to deploy more than 1.5 million smart meters across our utilities in the next five years – giving our customers greater access to real-time energy use data and providing even more customer control and choice.

We have great confidence that these big initiatives are sound investments that will generate reliable returns

and ensure Emera remains a leader in our evolving industry. But we also recognize that technology, customer trends and regulatory sentiments are shifting and evolving. And while we cannot predict with 20/20 clarity the outcomes of these changes, I am confident that we have the right innovation stance and the right portfolio of businesses for future growth. We are taking the right steps to review and adjust our strategy, to test new technologies and approaches and to position ourselves to continue to be ready to identify and seize the right solutions for our business.

A STRONG TEAM DELIVERING OPERATIONAL EXCELLENCE

It’s the commitment, expertise and hard work of our team right across the business that enables us to grow and deliver results.

Safety is our number one priority. In 2018, we made measurable progress on our journey to world-class safety by implementing a new Safety Management Program across Emera’s operating companies. Our reinforced commitment is reflected in better year-over-year safety performance. We improved our governance and our safety systems, and we further strengthened our speak up culture. But we know we still have work to do. We remain steadfast in our focus on becoming an Emera where no one gets hurt.

We continued our focus on being an employer of choice, attracting and retaining the best employees to deliver on our strategy. In 2018, we invested in new tools for our team, including Leadership Competencies and improved employee communications. Emera is proud to be recognized as one of Canada’s Best Employers by Forbes magazine

and one of Canada’s Top 100 Employers in 2019.

Sustainability is core to everything we do. In 2018, we continued to make energy cleaner, to build stronger communities and to respect the environment. Our strategy to reduce carbon intensity is a key part of our sustainability commitment, and our progress on carbon reduction is significant. While the nature of our industry and the history of the generation mix in the regions where we operate mean we do have some high-carbon-emitting infrastructure today, Emera is one of the companies making a difference in the reduction of carbon emissions, as we continue to execute on our strategy. In this light, we are proud to be named one of Canada’s Best 50 Corporate Citizens in 2018 by Corporate Knights for our sustainability commitments and results.

I would like to thank our Chair, Jackie Sheppard, and the entire Board for their insight and guidance. I appreciate their ongoing leadership and support, especially in such a significant year of transition for our company.

Clearly, 2018 was both a challenging and successful year for Emera. In the face of it all, our team stayed focused and did what we do best – work safely, execute with discipline and innovate for new opportunities and solutions. I’m incredibly proud and grateful to lead our dedicated team during this exciting time for our company and our industry.

 

LOGO

Scott Balfour

President and Chief Executive Officer, Emera

 

 

EMERA 2018 ANNUAL REPORT

10


FINANCIAL REVIEW

 

Forward-looking Information

     13  

Introduction and Strategic Overview

     14  

Non-GAAP Financial Measures

     15  

Consolidated Financial Review

     17  

Significant Items Affecting Earnings

     17  

Consolidated Financial Highlights by Business Segment

     18  

Consolidated Income Statement

  

Highlights

     19  

Business Overview and Outlook

     23  

Emera Florida and New Mexico

     23  

NSPI

     25  

Emera Maine

     26  

Emera Caribbean

     26  

Emera Energy

     27  

Corporate and Other

     28  

Consolidated Balance Sheet Highlights

     30  

Developments

     31  

Outstanding Common Stock Data

     32  

Financial Highlights

     33  

Emera Florida and New Mexico

     33  

NSPI

     38  

Emera Maine

     41  

Emera Caribbean

     43  

Emera Energy

     45  

Corporate and Other

     50  
Liquidity and Capital Resources      51  

Consolidated Cash Flow Highlights

     52  

Working Capital

     53  

Contractual Obligations

     53  

Forecasted Gross Consolidated

  

Capital Expenditures

     54  

Debt Management

     54  

Credit Ratings

     55  

Share Capital

     55  
Pension Funding      56  
Off-Balance Sheet Arrangements      56  
Dividend Payout Ratio      57  
Transactions with Related Parties      57  
Enterprise Risk and Risk Management      57  
Risk Management including Financial   
Instruments      65  
Disclosure and Internal Controls      67  
Critical Accounting Estimates      68  
Changes in Accounting Policies   
and Practices      72  
Future Accounting Pronouncements      74  
Summary of Quarterly Results      75  
Management Report      76  
Independent Auditor’s Report      77  
Report of Independent Registered Public Accounting Firm      79  
Consolidated Financial Statements      80  
Notes to the Consolidated Financial Statements      86  
Emera Leadership and Board      153  
Shareholder Information      154  
 

 

EMERA 2018 ANNUAL REPORT

11


MANAGEMENT’S DISCUSSION & ANALYSIS

 

 

MANAGEMENT’S DISCUSSION & ANALYSIS

As at February 15, 2019

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 2018 relative to the same quarter in 2017; the full year of 2018 relative to 2017 and selected financial information for 2016; and its financial position as at December 31, 2018 relative to December 31, 2017. To enhance shareholders’ understanding, certain multi-year historical financial and statistical information is presented. 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 currently carried out through six business segments: Emera Florida and New Mexico, Nova Scotia Power Inc., Emera Maine, Emera Caribbean, Emera Energy and Corporate and Other. The Company is reviewing its internal reporting to the chief operating decision maker and considering changes to its reportable segments for 2019.

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, 2018. 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. Emera’s rate-regulated subsidiaries 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”)

Peoples Gas System (“PGS”) – Gas Division of TEC    FPSC
SeaCoast Gas Transmission, LLC (“SeaCoast”)    FPSC
New Mexico Gas Company, Inc. (“NMGC”)    New Mexico Public Regulation Commission (“NMPRC”)
Nova Scotia Power Inc. (“NSPI”)    Nova Scotia Utility and Review Board (“UARB”)
Emera Maine    Maine Public Utilities Commission (“MPUC”) and FERC
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”)
Emera Brunswick Pipeline Company Limited (“Brunswick Pipeline”)    National Energy Board (“NEB”)
Equity Investments     
NSP Maritime Link Inc. (“NSPML”)    UARB

Maritimes & Northeast Pipeline Limited Partnership and Maritimes & Northeast Pipeline LLC (“M&NP”)

   NEB and FERC
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”)

All amounts are in Canadian dollars (“CAD”), except for the Emera Florida and New Mexico, Emera Maine and Emera Caribbean 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.

 

EMERA 2018 ANNUAL REPORT

12


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, 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”, “could”, “estimates”, “expects”, “intends”, “may”, “plans”, “projects”, “schedule”, “should”, “budget”, “forecast”, “might”, “will”, “would”, “targets” 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 are discussed in the “Business Overview and Outlook” section of the MD&A and may also include: regulatory risk; operating and maintenance risks; changes in economic conditions; commodity price and availability risk; liquidity and capital market risk; market for, pricing and timing of select asset sales; 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; weather; unanticipated maintenance and other expenditures; system operating and maintenance risk; derivative financial instruments and hedging; interest rate risk; counterparty credit risk; commercial relationship 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; 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.

 

EMERA 2018 ANNUAL REPORT

13


MANAGEMENT’S DISCUSSION & ANALYSIS

 

 

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 is to safely deliver cleaner, affordable and reliable energy to its customers.

Approximately 70 per cent of Emera’s current adjusted earnings are generated from operations in Florida and Nova Scotia. These jurisdictions provide generally stable regulatory and strong economic environments. Approximately 50 per cent of Emera’s assets and current adjusted earnings are from its operations in Florida.

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”), the amount of equity in the capital structure and the return on equity as allowed through regulation. Earnings are also affected by sales volumes and operating expenses.

Emera has a $6.5 billion capital investment plan over the 2019 to 2021 period, including investing $2.2 billion ($1.7 billion USD) in Florida for Tampa Electric’s 600 megawatts (“MW”) of new solar generation and the modernization of the Big Bend Power Station. This planned capital investment will be funded primarily through internally generated cash flows, debt raised at the operating company level and select asset sales. Equity capital markets, including the issuance of common and preferred equity and the dividend reinvestment plan will continue to support the company’s future capital investments. Maintaining investment-grade credit ratings is a key priority of management.

Emera has provided annual dividend growth guidance of four to five per cent through to 2021. 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 in 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 also impacted by movements in the US dollar relative to the Canadian dollar and benefits from a weaker Canadian dollar. Emera generally hedges transactional exposure (but does not hedge translational exposure). These impacts, as well as the timing of capital investment 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 unprecedented change and Emera is well positioned to respond to shifting customer demands, complex regulatory environments and the trend towards de-carbonization. Renewable generation and battery storage are getting both more affordable and efficient. Customers are looking for more choice, control and reliability. 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. Emera sees opportunity in these changes. Emera’s efforts to fund investments in renewable and technology assets with related fuel or operating cost savings balances the opportunity with managing rate pressure and affordability for customers.

For example, significant investments to facilitate the use of renewable and low-carbon energy include the recently completed Maritime Link in Atlantic Canada, the ongoing construction of new solar generation at Tampa Electric, and the modernization of the Big Bend Power Station at Tampa Electric. All of these projects demonstrate Emera’s strategy of finding cleaner ways to meet the energy needs of customers while keeping rates affordable.

Emera is committed to world-class safety, operational excellence, good governance, excellent customer service, reliability, being an employer of choice, and building constructive relationships with regulators, stakeholders and the communities where we operate.

 

EMERA 2018 ANNUAL REPORT

14


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 and the impact in 2017 of US tax reform, signed into law on December 22, 2017 in the US Tax Cuts and Jobs Act of 2017 (“the Act”).

The MTM adjustments are a result of the following:

 

   

the mark-to-market 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 mark-to-market 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 mark-to-market adjustments related to an interest rate swap in Brunswick Pipeline; and

   

the mark-to-market adjustments related to equity securities held in Emera Caribbean and Corporate and Other.

Management believes excluding from net income the effect of these mark-to-market 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 mark-to-market adjustments for evaluation of performance and incentive compensation.

In Q4 2017, the Company recorded a non-cash income tax expense resulting from the provisional revaluation of existing US non-regulated net deferred income tax assets. No further adjustments were recognized in 2018 and the Company has completed its accounting for this revaluation. The revaluation of an existing asset is not the result of any operational or market driven event. Management therefore believes excluding from net income the effect of this revaluation better distinguishes ongoing operations of the business, and allows investors to better understand and evaluate the Company.

Refer to the “Consolidated Financial Review” section and the “Financial Highlights” sections for Emera Energy, Emera Caribbean and Corporate and Other, for further details on mark-to-market adjustments.

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
 
            2018                 2017                     2018                 2017                2016  

Net income (loss) attributable to common shareholders

  $   231      $      (228      $      710      $      266     $      227  

Revaluation of US non-regulated deferred income taxes

  $   –      $      (317      $           $      (317   $       

After-tax mark-to-market gain (loss)

  $   64      $      (48        $      39      $      59     $      (248

Adjusted net income attributable to common shareholders

  $   167      $          137          $      671      $      524     $      475  

Earnings per common share – basic

  $   0.98      $      (1.06        $      3.05      $      1.25     $      1.33  

Adjusted earnings per common share – basic

  $       0.71      $          0.64              $      2.88          $          2.46     $          2.77  

 

EMERA 2018 ANNUAL REPORT

15


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 in assessing 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 mark-to-market adjustments.

The Company’s EBITDA and Adjusted EBITDA may not be comparable to 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
 
                     
                  2018                  2017                 2018                  2017              2016  

Net income (loss) (1)

   $          231      $          (232   $          747      $          299     $     266  

Interest expense, net

        186           175          713           698         585  

Income tax expense (recovery)

        40           329          69           520         (22

Depreciation and amortization

              229                 212                916                 856           588  

EBITDA

              686                 484                2,445                 2,373           1,417  

Mark-to-market gain (loss), excluding income tax and interest

              94                 (75              58                 78           (327

Adjusted EBITDA

   $          592      $          559     $          2,387      $          2,295     $     1,744  

 

(1)

Net income (loss) is income before Non-controlling interest in subsidiaries and Preferred stock dividends.

 

EMERA 2018 ANNUAL REPORT

16


MANAGEMENT’S DISCUSSION & ANALYSIS

 

 

CONSOLIDATED FINANCIAL REVIEW

SIGNIFICANT ITEMS AFFECTING EARNINGS

Earnings Impact of After-Tax Mark-to-Market Gains and Losses

After-tax mark-to-market increased $112 million to a $64 million gain in Q4 2018, compared to a $48 million loss in Q4 2017, mainly due to changes in Emera Energy’s existing contract positions. For the year ended December 31, 2018, after-tax mark-to-market gains decreased $20 million to $39 million, compared to $59 million in 2017. This decrease, primarily related to Emera Energy, was due to a larger reversal of mark-to-market losses in Q1 2017 and changes in existing contract positions, partially offset by lower amortization of gas transportation assets in 2018.

Florida State Tax Apportionment

In Q3 2018, Emera received approval from the Florida Department of Economic Opportunity to change its Florida state tax apportionment factors. This change resulted in the Company recording a tax benefit of approximately $23 million, or $0.10 per common share, as a result of the remeasurement of certain deferred tax balances.

US Tax Reform

On December 22, 2017, the Tax Cuts and Jobs Act of 2017 was signed into law. As a result, in Q4 2017, the Company was required to revalue its US deferred income tax assets and liabilities based on the new 21 per cent tax rate. The Company recognized a $317 million income tax expense in 2017 as a result of the provisional revaluation of its US non-regulated net deferred income tax assets. There was no impact to earnings on the revaluation of the utilities’ net deferred tax liabilities as the Act allowed for an offsetting regulatory liability.

No further adjustments were recognized in 2018 and the Company has completed its accounting for this revaluation. The measurement period allowed by SEC Staff Accounting Bulletin 118, Income Tax Accounting Implications of the Tax Cuts and Jobs Act (“SAB 118”) is now closed.

On November 26, 2018, the Internal Revenue Service (“IRS”) issued proposed regulations on the interest deductibility limitation rules legislated under the Act. The Company believes its US based financing interest will be deductible under the Act.

Emera’s effective tax rate for 2018 was 8 per cent. Absent the reduction of the US federal corporate income tax rate, the effective tax rate would have been 13 per cent. For further details on the effective tax rate, refer to note 7 to the consolidated financial statements for the year ended December 31, 2018.

 

EMERA 2018 ANNUAL REPORT

17


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

 

  

2018

 

   

2017

 

   

2018

 

   

2017

 

   

2016

 

 

Emera Florida and New Mexico

   $         101     $         80     $         428     $ 382     $ 172  

NSPI

     28       23       131       129       130  

Emera Maine

     11       8       44       46       47  

Emera Caribbean

     14       1       45       31       100  

Emera Energy

     44       26       120       24       24  

Corporate and Other

     (31     (1     (97     (88     2  
           

Adjusted net income attributable to common shareholders

   $ 167     $ 137     $ 671     $ 524     $ 475  

Revaluation of US non-regulated deferred income taxes

           (317           (317      

After-tax mark-to-market gain (loss)

     64       (48     39       59       (248

Net income (loss) attributable to common shareholders

   $ 231     $ (228 )            $ 710     $         266     $         227  

The following table highlights the significant changes in adjusted net income from 2017 to 2018:

 

For the

millions of Canadian dollars

   Three months ended
December 31
    Year ended
December 31

Adjusted net income – 2017

     $          137     $          524

Emera Energy

     18     96

Emera Florida and New Mexico

     21     46

Emera Caribbean

     13     14

NSPML and LIL equity earnings

     (4   14

Florida state tax apportionment

         23

Other

     (18   (46)
     

Adjusted net income – 2018

     $          167     $          671

Refer to the segment “Financial Highlights” section for further details of business unit contributions.

 

For the

millions of Canadian dollars

                 Year ended
December 31
 
       2018       2017       2016  

Operating cash flow before changes in working capital

   $   1,806     $   1,297     $ 919  

Change in working capital

     (116     (104     134  

Operating cash flow

   $ 1,690     $ 1,193     $ 1,053  

Investing cash flow

   $ (2,190   $ (1,761   $ (9,037

Financing cash flow

   $ 344     $ 593     $ 7,448  

As at

millions of Canadian dollars

                     December 31  
       2018       2017       2016  

Total assets

   $ 32,314     $     28,806     $ 29,271  

Total long-term debt (including current portion)

   $     15,411     $ 13,881     $ 14,744  

Refer to the “Consolidated Cash Flow Highlights” section for further discussion of cash flow.

 

EMERA 2018 ANNUAL REPORT

18


MANAGEMENT’S DISCUSSION & ANALYSIS

 

 

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
 
 
     

 

2018

 

   

 

2017

 

          

 

2018

 

   

 

2017

 

          

 

2016

 

 

Operating revenues

   $      1,799     $      1,473     $         326     $      6,524     $ 6,226     $ 298     $ 4,277  

Operating expenses

     1,368       1,231       (137     5,126       4,808       (318     3,722  

Income from operations

     431       242       189       1,398       1,418       (20     555  

Income from equity investments

     33       34       (1     154       124       30       100  

Other income (expenses)

     (7     (4     (3     (23     (25     2       174  

Interest expense, net

     186       175       (11     713       698       (15     585  

Income tax expense (recovery)

     40       329       289       69       520       451       (22

Net income (loss)

     231       (232     463       747       299       448       266  

Net income (loss) attributable to common shareholders

     231       (228     459       710       266       444       227  

Revaluation of US non-regulated deferred income taxes

           (317     317             (317     317        

After-tax mark-to-market gain (loss)

     64       (48     112       39       59       (20     (248

Adjusted net income attributable to common shareholders

   $ 167     $ 137     $ 30     $ 671     $ 524     $ 147     $ 475  

Earnings per common share – basic

   $ 0.98     $ (1.06   $ 2.04     $ 3.05     $ 1.25     $ 1.80     $ 1.33  

Earnings per common share – diluted

   $ 0.98     $ (1.06   $ 2.04     $ 3.04     $ 1.24     $ 1.80     $ 1.32  

Adjusted earnings per common share – basic

   $ 0.71     $ 0.64     $ 0.07     $ 2.88     $ 2.46     $ 0.42     $ 2.77  

Dividends per common share declared

   $     $     $     $ 2.2825     $ 2.1325     $     0.1500     $ 1.9950  
                                                          

Adjusted EBITDA

   $ 592     $ 559     $ 33     $ 2,387     $ 2,295     $ 92     $ 1,744  

Operating Revenues

For the fourth quarter of 2018, operating revenues increased $326 million, compared to the fourth quarter of 2017. Absent increased mark-to-market gains of $174 million, operating revenues increased $152 million due to:

 

   

$79 million increase at Emera Florida and New Mexico due to the impact of a stronger USD, higher electric sales volumes due to customer growth, weather and rates related to completed solar projects at Tampa Electric;

   

$30 million increase at NSPI as a result of increased sales volumes due to load growth and weather;

   

$35 million increase at Emera Energy reflecting significant pipeline maintenance that reduced marketing and trading margins on hedged capacity in Q4 2017 and higher capacity prices for its New England Gas Generation (“NEGG”) fleet in Q4 2018.

Operating revenues increased $298 million for the year ended December 31, 2018, compared to 2017. Absent decreased mark-to-market gains of $22 million, operating revenues increased $320 million due to:

 

   

$126 million increase at NEGG reflecting higher capacity prices and more favourable market conditions in 2018, and an unplanned outage at the Bridgeport facility in 2017;

   

$102 million increase at NSPI as a result of increased sales volumes due to load growth and weather, the 2017 refund to customers of 2016 over-recovery of fuel costs, and increased fuel-related electricity pricing, partially offset by the impact of the Maritime Link assessment;

   

$71 million increase in marketing and trading margin at Emera Energy Services (“EES”), driven primarily by the impact of cold weather in Q1 2018, warm weather in Q3 2018 and significant pipeline maintenance that reduced margins on hedged capacity in Q4 2017;

 

EMERA 2018 ANNUAL REPORT

19


MANAGEMENT’S DISCUSSION & ANALYSIS

 

 

   

$52 million increase at Emera Florida and New Mexico as a result of higher clause recoveries and favourable customer growth in PGS and favourable weather in Florida and New Mexico, higher electric sales volumes due to weather and higher base rates related to solar projects and the Polk Power Station expansion at Tampa Electric. These increases were partially offset by lower commodity costs in New Mexico; and

   

$26 million decrease at Bayside Power due to lower electricity sales reflecting renegotiation of the Bayside Power power purchase agreement (“PPA”).

Operating Expenses

For the fourth quarter of 2018, operating expenses increased $137 million, compared to the fourth quarter of 2017. Absent decreased mark-to-market gains of $3 million, operating expenses increased $134 million due to:

 

   

$90 million increase at Emera Florida and New Mexico as a result of increased operating, maintenance and general (“OM&G”) at Tampa Electric resulting from the regulatory agreement to net storm costs and the 2018 tax reform benefits, and the impact of a stronger USD;

   

$22 million increase at Corporate and Other mainly due to higher performance based compensation accruals; and

   

$14 million increase at NSPI due to increased fuel costs as a result of payment of the Maritime Link assessment and increased commodity prices, increased OM&G due to higher storm costs, partially offset by decreased fuel adjustment mechanism (“FAM”) and fixed cost deferrals.

Operating expenses increased $318 million for the year ended December 31, 2018, compared to 2017. Absent increased mark-to-market gains of $6 million, operating expenses increased $324 million due to:

 

   

$175 million increase at Emera Florida and New Mexico as a result of increased OM&G at Tampa Electric from the regulatory agreement to net storm costs and the 2018 tax reform benefits;

   

$88 million increase at NSPI due to increased fuel costs as a result of payment of the Maritime Link assessment and increased commodity pricing, partially offset by decreased FAM and fixed cost deferrals;

   

$60 million increase at NEGG due to an increase in generation volumes in 2018 reflecting the impact of the unplanned outage at Bridgeport Energy in 2017 and more favourable market conditions in 2018;

   

$56 million increase in depreciation and amortization due to normal asset growth across the business; and

   

$26 million decrease at Bayside Power due to decreased natural gas purchases reflecting renegotiation of the Bayside Power PPA.

Income from Equity Investments

Income from equity investments increased $30 million for the year ended December 31, 2018, compared to 2017, due to increased capacity prices at Bear Swamp and higher equity earnings from NSPML and LIL.

Income Tax Expense

The decrease in income tax expense for the fourth quarter of 2018, compared to the same period in 2017, was due to the reduction of the US federal corporate income tax rate, partially offset by increased income before provision for income taxes. The reduction of the US federal corporate income tax rate resulted in a $339 million decrease in income tax expense for the quarter, including the $317 million income tax expense recognized in Q4 2017 related to the revaluation of the Company’s US non-regulated net deferred income tax assets at the new tax rate.

The decrease in income tax expense for the year ended December 31, 2018, compared to 2017, was due to the reduction of the US federal corporate income tax rate, amortization of deferred tax regulatory liabilities in the US utilities and remeasurement of certain deferred tax balances as a result of a change in Florida state tax apportionment factors. The reduction of the US federal corporate income tax rate resulted in a $405 million decrease in income tax expense for the year ended December 31, 2018, including the $317 million income tax expense recognized in 2017 related to the revaluation of the Company’s US non-regulated net deferred income tax assets at the new tax rate.

 

EMERA 2018 ANNUAL REPORT

20


MANAGEMENT’S DISCUSSION & ANALYSIS

 

 

As a result of the US Tax Cuts and Jobs Act of 2017, the US federal corporate income tax rate was reduced from 35 per cent to 21 per cent. This reduction resulted in a significant decrease in income tax expense, as described above, however the net impact to earnings was minimal. This was a result of the favourable impact of the reduced tax rate on Emera Energy earnings which was offset by the unfavourable impact of reduced tax recovery on losses arising from Corporate borrowing costs. The net impact on US based regulated utilities earnings was immaterial. Tax benefits from the reduced rates in Tampa Electric were netted against deferred storm costs for 2018. Tax benefits deferred by PGS were netted against the amortization of its manufactured gas plant (“MGP”) environmental regulatory asset in 2018. Tampa Electric and PGS tax benefits will be adjusted in rates starting in 2019. As of December 31, 2018, NMGC recorded a regulatory liability of $8 million USD, to reflect 2018 tax reform benefits, which are being addressed through ongoing rate case proceedings. Certain of the tax benefits for Emera Maine are reflected in rates effective July 1, 2018 with other components being deferred to be addressed in future regulatory proceedings.

Net Income and Adjusted Net Income Attributable to Common Shareholders

For the fourth quarter in 2018, net income attributable to common shareholders was favourably impacted by the $317 million 2017 revaluation of US non-regulated deferred income taxes and the $112 million increase in after-tax mark-to-market gains primarily related to Emera Energy. Absent the 2017 revaluation of US non-regulated deferred income taxes and favourable mark-to-market changes, adjusted net income attributable to common shareholders increased $30 million due to higher contributions from Emera Energy and Emera Florida and New Mexico, partially offset by decreased contributions from Corporate and Other.

For the year ended December 31, 2018 net income attributable to common shareholders was favourably impacted by the $317 million 2017 revaluation of US non-regulated deferred income taxes, partially offset by the $20 million decrease in after-tax mark-to-market gains primarily related to Emera Energy. Absent the 2017 revaluation of US non-regulated deferred income taxes and unfavourable mark-to-market changes, adjusted net income attributable to common shareholders increased $147 million. The increase was due to higher contributions from Emera Energy, Emera Florida and New Mexico and NSPML and LIL, and the tax benefit recorded as a result of remeasurement of certain deferred tax balances due to the change in Florida state tax apportionment factors, partially offset by decreased contributions from Corporate and Other.

Earnings and Adjusted Earnings per Common Share – Basic

Earnings per common share – basic were higher for the fourth quarter and for the year ended December 31, 2018 due to the results of the revaluation of US non-regulated deferred income taxes in 2017 and higher earnings in 2018, partially offset by the impact of the increase in the weighted average number of common shares outstanding reflecting the issuance of shares in December 2017.

Adjusted earnings per common share – basic were higher for the fourth quarter and for the year ended December 31, 2018 due to higher adjusted earnings, partially offset by the increase in the weighted average of common shares outstanding.

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 Canadian dollars for financial reporting. Changes in translation rates, particularly in the value of the US dollar against the Canadian dollar, can positively or adversely affect results.

Earnings from Emera’s foreign operations are translated into Canadian dollars. In general, Emera’s earnings benefit from a weakening Canadian dollar and are adversely impacted by a strengthening Canadian dollar. The impact of foreign exchange in any period is driven by rate changes, the timing of earnings from foreign operations during the period, and the percentage of earnings from foreign operations in the period.

 

EMERA 2018 ANNUAL REPORT

21


MANAGEMENT’S DISCUSSION & ANALYSIS

 

 

Results of operations from 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 2018 and 2017 are as follows:

 

      
Three months ended
December 31
 
 
             
Year ended
December 31
 
 
    

 

 

 

 

2018

 

 

 

 

  

 

 

 

 

2017

 

 

 

 

  

 

 

 

 

2018

 

 

 

 

  

 

 

 

 

2017

 

 

 

 

Weighted average CAD/USD exchange rate

   $        1.32      $       1.27      $         1.30      $ 1.30  

Period end CAD/USD exchange rate

   $ 1.36      $ 1.25      $ 1.36      $ 1.25  

The weakening of the CAD increased earnings by $9 million and adjusted earnings by $7 million in Q4 2018 compared to Q4 2017. The weakening of the CAD increased earnings by $1 million and adjusted earnings by $4 million in 2018, compared to 2017.

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 short-term foreign currency derivative instruments to hedge specific transactions. 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 US dollar currency.

 

millions of US dollars

    
Three months ended
December 31
 
 
           
Year ended
December 31
 
 
       2018       2017       2018       2017  

Emera Florida and New Mexico

   $       77     $           63     $       331     $ 295  

Emera Maine

     9       7       34       36  

Emera Caribbean

     11       1       35       24  

Emera Energy (1)

     35       19       100       21  
     132       90       500       376  

Corporate and Other (2)

     (33     (29     (130     (116

Total (3)

   $       99     $           61     $ 370     $ 260  

 

(1)

Includes Emera Energy’s US dollar adjusted net income from EES, NEGG and Bear Swamp.

(2)

Corporate and Other includes interest expense on US dollar denominated debt, net of interest income on an intercompany US dollar loan to Emera Energy.

(3)

Amounts above do not include the impact of mark-to-market or US tax reform.

 

EMERA 2018 ANNUAL REPORT

22


MANAGEMENT’S DISCUSSION & ANALYSIS

 

 

BUSINESS OVERVIEW AND OUTLOOK

Earnings from Emera’s regulated utilities are most directly impacted by the rate of return on equity (“ROE”) or rate base and capital structure approved by their regulators, the prudent management of operating costs, the approved recovery of regulatory deferrals, energy sales volumes including the impact of weather, and the timing and amount of capital expenditures. Electric and gas sales volumes are primarily driven by general economic conditions, population and weather. Emera’s residential load generally comprises individual homes, apartments and condominiums. Commercial customers include small retail operations, large office and commercial complexes, universities and hospitals. The electric and gas utilities’ industrial customers include manufacturing facilities and other large volume operations.

EMERA FLORIDA AND NEW MEXICO

Emera Florida and New Mexico includes TECO Energy, the parent company of TEC, NMGC, SeaCoast and TECO Finance. TEC consists of two divisions; Tampa Electric, a vertically integrated regulated electric utility engaged in the generation, transmission and distribution of electricity serving customers in West Central Florida, and PGS, 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.

Tampa Electric

With approximately $7.8 billion USD of assets and approximately 764,000 customers at December 31, 2018, Tampa Electric owns 5,238 MW of generating capacity, of which 77 per cent is natural gas-fired, 20 per cent is coal and petroleum coke (“petcoke”) and 3 per cent is solar. Tampa Electric owns 2,150 kilometres of transmission facilities and 18,750 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.

Peoples Gas System

With approximately $1.4 billion USD of assets and approximately 392,000 customers, the PGS system includes approximately 20,920 kilometres of natural gas mains and 11,910 kilometres of service lines. Natural gas throughput (the amount of gas delivered to its customers, including transportation-only service) was 2.0 billion therms in 2018.

The approved ROE range for PGS is 9.25 per cent to 11.75 per cent, based on an allowed equity capital structure of 54.7 per cent. Absent any rate case filing, the bottom of the range will increase to 9.75 per cent in 2021. An ROE of 10.75 per cent is used for the calculation of return on investments for clauses.

New Mexico Gas Company, Inc.

With over $1.3 billion USD of assets and approximately 530,000 customers, NMGC serves approximately 60 per cent of the state’s population in 23 of New Mexico’s 33 counties. NMGC’s system includes approximately 2,640 kilometres of transmission lines and 17,040 kilometres of distribution lines. Annual natural gas throughput was approximately 825 million therms in 2018.

The approved ROE for NMGC is 10 per cent, on an allowed equity capital structure of 52 per cent. NMGC’s rates were established in a 2012 rate case settlement and were frozen until December 31, 2017 per the June 2016 NMPRC order (the “Order”) approving Emera’s acquisition of TECO Energy. NMGC filed a rate case, including the prospective impact of tax reform, on February 26, 2018. A hearing in the rate case was held September 24, 2018, when an uncontested stipulation on the rate request was presented. A second hearing in the rate case, related to 2018 tax reform benefits, was held December 17, 2018. Decisions by the NMPRC on the rate case and on 2018 tax reform benefits are expected in 2019.

 

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Emera Florida and New Mexico Outlook

The Florida utilities anticipate earning within their allowed ROE ranges in 2019 and expect rate base and earnings to be higher than prior years. Tampa Electric expects customer growth rates in 2019 to be consistent with 2018, reflective of economic growth in Florida. Assuming normal weather in 2019, Tampa Electric sales volumes are expected to be consistent with 2018 sales volumes which benefited from favourable weather. PGS expects customer growth rates in 2019 to be consistent with 2018, reflective of economic growth in Florida and the optimization of existing opportunities as the utility increases its market penetration in Florida. Assuming normal weather in 2019, PGS sales volumes are expected to increase at a level lower than customer growth as 2018 energy sales benefited from favourable weather.

In September 2018, Tampa Electric announced its intention to invest approximately $235 million USD during 2018 through 2022 for its advanced metering infrastructure (“AMI”) project.

In May 2018, Tampa Electric announced its intention to invest approximately $850 million USD during 2018 through 2023 to modernize the Big Bend Power Station. Refer to the “Developments” section for further details.

In September 2017, Tampa Electric announced its intention to invest approximately $850 million USD over four years in new utility-scale solar photovoltaic projects across its service territory. On November 6, 2017, the FPSC approved a settlement agreement allowing a solar base rate adjustment (“SoBRA”) that provides for the recovery, upon in-service, of up to 600 MW of investments in utility-scale solar projects phased in from late 2018 through early 2021. On May 8, 2018, the FPSC approved Tampa Electric’s first SoBRA. This SoBRA represents 145 MW and $24 million USD annually in estimated revenue requirements and Tampa Electric began collecting these revenues in September 2018. On October 29, 2018, the FPSC approved Tampa Electric’s second SoBRA. This SoBRA represents 260 MW and $46 million USD annually in estimated revenue requirements and Tampa Electric began collecting these revenues in January 2019.

In September 2017, Tampa Electric was impacted by Hurricane Irma and incurred restoration costs of approximately $102 million USD. The amount charged to the storm reserve exceeded the balance in the reserve by $47 million USD. On December 28, 2017, Tampa Electric petitioned the FPSC for recovery of estimated restoration costs in excess of the storm reserve for several named storms and to replenish the reserve to the $56 million USD level that existed as of October 31, 2013. On March 1, 2018, the FPSC approved a settlement agreement filed by Tampa Electric authorizing the utility to net the amount of storm cost recovery against its return of estimated 2018 US tax reform benefits to customers, effective April 1, 2018. In Q1 2018, Tampa Electric recorded OM&G expense and a regulatory liability of $19 million USD to offset tax reform benefits. This deferral was amortized over the balance of the year as a credit against recognition of storm expense. In total, OM&G expense due to the allowed netting of the storm cost recovery with tax reform benefits, net of amortization of first quarter tax reform benefits, was approximately $22 million USD for Q4 2018 and $103 million USD for the year ended December 31, 2018.

Tampa Electric’s final storm costs subject to netting will be determined in a separate regulatory proceeding in 2019. Any difference will be trued up and returned to customers in 2020. On August 20, 2018, the FPSC approved a reduction in base rates of $103 million USD annually beginning in 2019 to reflect the impact of tax reform.

On September 12, 2018, the FPSC approved a settlement agreement filed by PGS, authorizing the utility to amortize $11 million USD of its MGP environmental regulatory asset and net it against its estimated 2018 tax reform benefits. Beginning in January 2019, PGS lowered base rates by $12 million USD to reflect the impact of tax reform and reduced depreciation rates by $10 million USD, in accordance with the settlement agreement.

NMGC expects 2019 earnings and rate base to be higher than prior years. Customer growth rates are expected to be consistent with 2018, reflecting expectations for housing starts and new connections.

In 2019, Emera Florida and New Mexico expects to invest approximately $1.3 billion USD in capital projects, including allowance for funds used during construction (“AFUDC”), compared to $1.2 billion USD in 2018. Capital projects include supporting normal system reliability and growth at the three utilities. Tampa Electric’s investments include the modernization of the Big Bend Power Station, solar projects and AMI. AFUDC will be earned during the construction periods.

 

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PGS will make investments in 2019 to expand its system and support customer growth, including expected investments related to compressed natural gas fueling stations and liquefied natural gas facilities, and continued replacement of obsolete plastic, cast iron and bare steel pipe.

On April 4, 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 will construct and operate a 21-mile, 30-inch pipeline lateral that is anticipated to go into service by 2022. The estimated capital investment is projected to be in the range of $100 million to $120 million USD with the majority of the investment expected in 2020 and 2021.

NMGC will complete planning phases of the Santa Fe Mainline Looping project in 2019, and will continue to invest in system improvements by replacing legacy pipe and making pipeline integrity management improvements.

NSPI

NSPI is a vertically integrated regulated electric utility. It is the primary electricity supplier in Nova Scotia, Canada. NSPI has approximately $5.1 billion of assets and provides electricity generation, transmission and distribution services to approximately 519,000 customers. The Company owns 2,441 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”). These IPPs own 546 MW of capacity. NSPI owns approximately 5,000 kilometres of transmission facilities and 27,000 kilometres of distribution facilities.

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 2019 and expects modest rate base growth which will deliver a similar modest increase in earnings.

In December 2015, the Electricity Plan Implementation (2015) Act (“Electricity Plan Act”) was enacted by the Province of Nova Scotia with a goal of providing rate stability and predictability for customers for the 2017 through 2019 period. NSPI is currently operating under a Rate Stability Plan for fuel costs for 2017 through 2019 which includes an average annual rate increase of 1.5 per cent for each of these three years.

Although the market in Nova Scotia is otherwise mature, the transformation of energy supply to lower emission sources has driven organic growth within NSPI as investments have been made in renewable generation and system reliability projects.

NSPI is subject to environmental regulations as set by both the Province of Nova Scotia and the Government of Canada. NSPI continues to work with both levels of government to comply with these regulations, maximizing efficiency of emission control measures and minimizing customer cost. NSPI anticipates that any costs prudently incurred to achieve the legislated reductions will be recoverable from customers under NSPI’s regulatory framework.

The Government of Canada (“the Government”) introduced the Pan-Canadian Framework on Clean Growth and Climate Change (“the Framework”) in early 2017. As part of the Framework, in February 2018, the Government introduced proposed changes to the greenhouse gas (“GHG”) coal regulations designed to remove coal fired generation by 2030, subject to equivalency agreements. At that time, a regulation was introduced specifying the emission intensities required for new natural gas fired generation and for boiler conversions from coal to natural gas. The Government published final regulations for both coal and natural gas generation in December 2018. NSPI expects the changes to equivalency agreements to be finalized in 2019. This agreement allows NSPI to achieve compliance with federal GHG emissions regulations by meeting provincial legislative and regulatory requirements as they are deemed to be equivalent. Beginning January 1, 2019, each province and territory in Canada is required to have a carbon pricing system which meets a benchmark set by the Government. On October 23, 2018, the Government of Canada confirmed that the cap and trade carbon pricing system proposed by the Government of Nova Scotia met the federal benchmark. The Government of Nova Scotia has published final details on the program regarding registration and operating rules. NSPI was granted 22 million metric tons of carbon dioxide allowances for the four year compliance period of 2019 through 2022. The Government of Canada is continuing to develop a clean fuel standard with the expectation that it will not apply to the electricity sector until 2022 at the earliest. NSPI anticipates any prudently incurred costs required to comply with the Framework, and the cap and trade pricing system, will be recoverable from customers.

 

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In November 2018, the Government of Canada presented the 2018 Federal Fall Economic Statement (“the Statement”). The Statement introduced proposed legislation that will provide for the immediate expensing of 100 per cent of the cost of specified clean energy equipment and increased first-year tax depreciation for eligible property. Once enacted, these measures will apply to eligible property that is acquired after November 20, 2018 and available for use before 2028. These measures will impact the timing of tax deductions related to NSPI’s investment in property, plant and equipment.

In June 2018, the UARB approved NSPI’s $133 million capital application to upgrade customers to AMI. NSPI will commence installation of AMI in 2019 and expects the full AMI project to be completed in 2021.

In 2019, NSPI expects to invest approximately $340 million, including AFUDC, in capital projects, compared to $348 million in 2018. NSPI is investing in projects which will support system reliability and AMI.

EMERA MAINE

Emera Maine is a transmission and distribution (“T&D”) regulated electric utility with assets of approximately $1.2 billion USD serving approximately 159,000 customers in the State of Maine. Emera Maine owns and operates approximately 2,000 kilometres of transmission facilities and 10,000 kilometres of distribution facilities. Electricity generation is deregulated in Maine, and several suppliers compete to provide customers with the energy delivered through Emera Maine’s T&D networks.

Approximately 44 per cent of Emera Maine’s operating revenue represents distribution operations, 46 per cent is associated with transmission operations and 10 per cent relates to stranded cost recoveries. The rates for each element are established in distinct regulatory proceedings.

In June 2018, the MPUC approved a 5.3 per cent distribution rate increase. This increase was effective July 1, 2018 and is based on a 9.35 per cent ROE and a common equity component of 49 per cent. Prior to July 1, 2018, the allowed ROE was 9.0 per cent, on a common equity component of 49 per cent.

There are currently four pending complaints filed with the FERC to challenge the base ROE under the ISO-New England (“ISO-NE”) Open Access Transmission Tariff (“OATT”). On October 16, 2018, the FERC issued an order that addressed all four complaint proceedings. The FERC order proposed a new methodology to set ROEs. Based on the new methodology, the FERC’s preliminary finding was a 10.41 per cent base ROE for the ISO-NE OATT. The FERC has permitted parties to comment on the new methodology and its application to the four pending complaint proceedings. The current reserve is expected to be sufficient to cover the impact of this preliminary finding. For further discussion on the complaints, refer to note 26 to the consolidated financial statements for the year ended December 31, 2018.

Emera Maine’s 2019 rate base is expected to grow modestly due to ongoing investment in transmission and distribution infrastructure, resulting in modest growth in earnings.

In 2019, Emera Maine expects to invest approximately $70 million USD (2018 – $76 million USD), primarily on transmission and distribution capital projects supporting normal system reliability.

EMERA CARIBBEAN

Emera Caribbean represents Emera (Caribbean) Incorporated (“ECI”), a holding company with regulated electric utilities including BLPC, a vertically integrated utility that is the sole provider of electricity in Barbados; GBPC, a vertically integrated utility that is the sole provider of electricity on Grand Bahama Island and a 51.9 per cent interest in Domlec, a vertically integrated utility on the island of Dominica. ECI also holds a 19.1 per cent indirect interest in Lucelec, a vertically integrated utility on the island of St. Lucia which is accounted for on the equity basis.

BLPC

With approximately $380 million USD of assets and approximately 130,000 customers, BLPC owns 249 MW of generating capacity, of which 96 per cent is oil-fired and 4 per cent is solar. BLPC owns approximately 168 kilometres of transmission facilities and 2,800 kilometres of distribution facilities. BLPC’s approved regulated return on rate base is 10.0 per cent.

 

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GBPC

With approximately $300 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. In December 2018, the GBPA approved GBPC’s regulated return on rate base of 8.44 per cent for 2019. On January 15, 2018, Emera completed the acquisition of the common shares held by the minority shareholders of ICD Utilities Limited (“ICDU”), increasing the Company’s interest in GBPC from 80.4 per cent to 100 per cent.

Domlec

Domlec serves approximately 26,000 customers. Domlec owns 27 MW of generating capacity of which 74 per cent is oil-fired and 26 per cent is hydro. Domlec owns approximately 452 kilometres of transmission facilities and 635 kilometres of distribution facilities. Domlec’s approved regulated return on rate base is 15.0 per cent.

Emera Caribbean Outlook

With oil being the predominant fuel source for generation of electricity in the Caribbean, and with fuel costs directly passed through electricity rates to customers, any change in global fuel prices and resulting change in fuel costs will result in a similar change in customer rates and reported revenues. GBPC has implemented fuel hedging strategies to provide increased certainty to customers as to fuel costs and electricity rates. In support of reducing carbon emissions and exposure to carbon-based fuel sources, more efficient and renewable energy generation and battery storage investments are being developed in the Caribbean.

In 2018, S&P issued several long- and short-term currency ratings changes and changes in ratings on certain bonds for Barbados. These ratings changes are not expected to have a material impact on BLPC.

On December 18, 2018, the Government of Barbados signed the Income Tax Amendment Act into law. The legislation, 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 its new lower corporate income tax rate, resulting in recognition of an income tax recovery, the majority of which was deferred as a regulatory liability. These changes had minimal impact on 2018 earnings and are expected to have minimal impact on future earnings.

Earnings from Emera Caribbean’s utilities in 2019 are expected to be consistent with 2018.

Emera Caribbean plans to invest approximately $120 million USD in capital programs in 2019 (2018 – $68 million USD). This increase is due to investment in new, efficient oil based generation and renewable generation partially offset by lower spending at Domlec due to the completion of hurricane restoration in 2018.

EMERA ENERGY

Emera Energy includes Emera Energy Services (“EES”), a wholly owned physical energy marketing and trading business; Emera Energy Generation (“EEG”), a wholly owned portfolio of electricity generation facilities in New England and the Maritime provinces of Canada; 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. On November 26, 2018, Emera announced an agreement to sell its three New England Gas Generating facilities. The transaction is expected to close in the first quarter of 2019. Refer to the “Developments” section for further details.

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 generally providing the greatest opportunity for earnings. Under normal market conditions, the business is generally expected to deliver 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.

Earnings from EEG’s assets are largely dependent on market conditions, particularly the relative pricing of electricity and natural gas and the absolute price of natural gas as the marginal fuel in the supply stack, and capacity pricing in ISO-NE for NEGG. Efficient operations of the fleet to ensure unit availability, cost management, and effective commercial management are key success factors. Earnings from EEG will be lower in 2019 due to the pending sale of the NEGG facilities.

In 2019, Emera Energy expects to invest approximately $10 million (2018 – $34 million) in capital projects related to its generating assets to continue to improve reliability. This decrease is due to the expected sale of the NEGG facilities.

 

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CORPORATE AND OTHER

Corporate

Corporate encompasses certain corporate-wide functions including executive management, strategic planning, treasury services, legal, financial reporting, tax planning, corporate business development, corporate governance, internal audit, investor relations, risk management, insurance, acquisition-related costs and corporate human resource activities. It also includes interest revenue on intercompany financings recorded in “Intercompany revenue” and costs associated with corporate activities that are not directly allocated to the operations of Emera’s subsidiaries and investments.

Other

Other includes the following consolidated and non-consolidated investments:

Consolidated Investments

 

   

Brunswick Pipeline, a regulated 145-kilometre pipeline that transports natural gas from Saint John, New Brunswick, to markets in the northeastern United States. The pipeline is contracted under a 25-year firm service agreement with Repsol Energy Canada that expires in 2034. The service agreement is accounted for as a direct financing lease.

   

Emera Reinsurance Limited, a captive insurance company providing insurance and reinsurance to Emera and certain of its affiliates, to enable more cost efficient management of risk and deductible levels across Emera.

   

Emera Utility Services (“EUS”), a utility services contractor primarily operating in Atlantic Canada.

   

Emera US Holdings Inc., a wholly owned holding company for certain of Emera’s assets located in the United States.

   

Emera US Finance LP, a wholly owned financing subsidiary of Emera.

   

Emera Newfoundland & Labrador Holdings Inc. (“ENL”), holding Emera’s non-consolidated investments in NSPML and LIL which are accounted for on the equity basis. These two transmission investments are related to the development of an 824 MW hydroelectric generating facility at Muskrat Falls on the Lower Churchill River in Labrador. See below for additional information on ENL.

Non-consolidated Investments Accounted for on the Equity Basis

 

   

Emera’s 100 per cent investment in NSPML, a $1.56 billion transmission project, including two 170-kilometre subsea cables, connecting the island of Newfoundland and Nova Scotia. This project completed commissioning and entered service on January 15, 2018.

   

Emera’s 49.5 per cent investment in the partnership capital of 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 the energization phase of the project began in June 2018. On June 27, 2018, Nalcor Energy recognized the first flow of energy from Labrador to Newfoundland and continues to work towards finalizing commissioning activities.

   

Emera’s 12.9 per cent investment in M&NP.

Corporate and Other includes corporate financing costs, earnings as a result of the equity investment in Maritime Link and the Labrador Island Link, project-based construction services activity by Emera Utility Services and capital lease accounting treatment of the Emera Brunswick Pipeline, which yields declining earnings over the life of the asset. The segment also includes corporate related costs that are dependent on the level of business development activity and acquisition-related initiatives.

 

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Corporate and Other’s costs are expected to be higher in 2019 due to lower intercompany revenue on intercompany financings as a result of the expected sale of NEGG facilities in Q1 2019; increased preferred dividend expense due to additional preferred shares issued in 2018; and lower tax recoveries due to the change in Florida state tax apportionment factors that resulted in the remeasurement of certain deferred tax balances in 2018.

Corporate and Other, excluding ENL as discussed below, expects to spend approximately $10 million on property, plant and equipment in 2019 (2018 – $41 million).

ENL

NSP Maritime Link Inc. (“NSPML”)

Through its subsidiary, NSP Maritime Link Inc., ENL has invested, $1.8 billion of equity, debt and working capital, including $209 million of AFUDC, in development of the Maritime Link Project. Project to date, ENL has invested $545 million in equity, comprised of $452 million in equity contributed and $93 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 entered service on January 15, 2018 and provides for the transmission of energy as well as 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. In Q1 2018, NSPML began recording cash earnings and collecting UARB approved cash payments from NSPI. Prior to Q1 2018, NSPML recorded non-cash AFUDC earnings as it was under construction. All major contracts have been concluded.

Future equity earnings contributions from the Maritime Link are dependent on the approved ROE and operational performance of NSPML. The approved ROE is 9 per cent.

In 2019, NSPML expects to invest approximately $20 million in capital related to construction close-out costs.

Labrador Island Link (“LIL”)

ENL is a limited partner with Nalcor Energy in LIL, with total project costs currently 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.

Earnings from the LIL investment are based on the book value of the equity investment and the approved ROE. Emera’s current equity investment is $534 million, and is forecasted to be $579 million by the end of 2019, comprised of $410 million in equity contribution and an estimated $169 million of accumulated equity earnings. Emera’s total equity contribution in the LIL, excluding accumulated equity earnings, is estimated to be approximately $600 million by 2020 when all Lower Churchill projects, including Muskrat Falls, are forecasted by Nalcor Energy to be placed in service.

Cash earnings and return of equity are forecasted by Nalcor Energy to begin in 2020 and until that point Emera will continue to record AFUDC earnings, with such earnings capitalized to its equity investment.

Equity earnings from NSPML and LIL are expected to be modestly higher in 2019 compared to 2018. Both the NSPML and LIL investments are recorded as “Investments subject to significant influence” on Emera’s Consolidated Balance Sheets.

 

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CONSOLIDATED BALANCE SHEET HIGHLIGHTS

Significant changes in the Consolidated Balance Sheets between December 31, 2017 and December 31, 2018 include:

 

millions of Canadian dollars    Increase    
(Decrease)    
   Explanation
Assets      

Cash and cash equivalents

   $        (122)        Decreased due to additions of property, plant, and equipment and payment of common dividend. These were partially offset by increased cash from operations, changes in borrowings and the issuance of preferred shares.

Inventory

   56         Increased due to the effect of a stronger USD on the translation of Emera’s foreign subsidiaries and increased fuel inventory as a result of higher volumes and higher commodity pricing at NSPI.

Derivative instruments (current and long-term)

   (86)        Decreased due to settlements of derivative instruments and lower commodity prices at NSPI.

Regulatory assets (current and long-term)

   158         Increased due to the effect of a stronger USD on the translation of foreign subsidiaries, increased fuel clauses at Tampa Electric and increased deferred income tax regulatory asset at NSPI, partially offset by decreased storm reserve at Tampa Electric.

Assets held for sale (current and long-term), net of liabilities

   810         Increased due to the pending sale of the NEGG facilities.

Property, plant and equipment, net of accumulated depreciation and amortization

   1,717         Increased due to additions at regulated utilities, and the effect of a stronger USD on the translation of Emera’s foreign subsidiaries, partially offset by the reclassification of NEGG facilities to assets held for sale and increased accumulated depreciation.

Investments subject to significant influence

   101         Increased due to investment in LIL and NSPML.

Goodwill

   508         Increased due to the effect of a stronger USD on the translation of Emera’s foreign subsidiaries.

Receivables and other assets (current and long-term)

   324         Increased primarily due to reclassification of alternative minimum tax credit carryforwards from deferred income tax liabilities at Emera Florida and New Mexico and higher gas transportation assets at Emera Energy.

 

Liabilities and Equity

     

Short-term debt and long-term debt (including current portion)

   1,475         Increased due to the effect of a stronger USD on foreign currency debt, increased borrowings under existing credit facilities, and increased borrowings of long-term debt at Emera Florida and New Mexico.

Accounts payable

   128         Increased due to the effect of a stronger USD on the translation of foreign subsidiaries and higher commodity volumes and prices at EES.

Deferred income tax liabilities, net of deferred income tax assets

   260         Increased due to tax deductions in excess of accounting depreciation related to property, plant and equipment, reclassification of alternative minimum tax credit carryforwards to receivables and other current assets at Emera Florida and New Mexico, and net utilization of tax loss carryforwards, partially offset by increased income tax credits primarily related to solar projects at Tampa Electric.

Derivative instruments (current and long-term)

   55         Increased due to the effect of a stronger USD on the translation of Emera’s foreign subsidiaries and new contracts at Emera Energy, partially offset by the reversal of 2017 asset management agreement mark-to-market losses.

Regulatory liabilities (current and long-term)

   142         Increased due to the effect of a stronger USD on the translation of Emera’s foreign subsidiaries and replenishment of the storm reserve at Tampa Electric, partially offset by increased deferrals related to derivative instruments at NSPI.

Pension and post-retirement liabilities

   82         Increased due to a decrease in fair value of plan assets at Emera Florida and New Mexico and the effect of a stronger USD on the translation of Emera’s foreign subsidiaries.

Other liabilities (current and long-term)

   155         Increased due to investment tax credits primarily related to solar projects at Tampa Electric and the effect of a stronger USD on the translation of Emera’s foreign subsidiaries.

Common stock

   215         Increased due to the dividend reinvestment plan and issuance of common stock for the purchase of additional shares of ICDU.

Cumulative preferred stock

   295         Increased due to the issuance of preferred shares.

Accumulated other comprehensive income

   503         Increased due to the effect of a stronger USD on the translation of Emera’s foreign subsidiaries.

Retained earnings

   184         Increased due to net income in excess of dividends paid.

Non-controlling interest in subsidiaries

   (51)        Decreased due to increased ownership in GBPC.

 

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DEVELOPMENTS

Pending Sale of Emera Energy’s New England Gas Generating Facilities

On November 26, 2018, Emera announced an agreement to sell its three NEGG facilities for $590 million USD plus a final working capital adjustment made on close. Proceeds from the sale of the NEGG facilities will be used to reduce corporate level debt and support capital investment opportunities within the regulated utility business. The transaction is expected to close in the first quarter of 2019 and is subject to certain regulatory approvals including approval of the FERC. The applicable provisions of the Hart-Scott-Rodino Antitrust Act have been satisfied.

Increase in Common Dividend

Effective August 9, 2018, Emera’s Board of Directors approved an increase in the annual common share dividend rate from $2.26 to $2.35. The first quarterly dividend payment at the increased rate was paid on November 15, 2018.

USGAAP Reporting Extension

On January 26, 2018, Emera was granted exemptive relief by Canadian securities regulators allowing Emera to continue to report its financial results in accordance with USGAAP (the “Exemptive Relief”). On July 18, 2018, Emera was granted an order pursuant to the Companies Act (Nova Scotia) exempting Emera from the Companies Act requirement to prepare its annual financial statements in accordance with International Financial Reporting Standards (“IFRS”) (the “Companies Act Relief”). Both the Exemptive Relief and the Companies Act Relief will remain in effect until the earlier of: (i) January 1, 2024; (ii) the first day of the Company’s financial year commencing after the Company ceases to have activities subject to rate regulation; and (iii) the effective date prescribed by the International Accounting Standards Board for the mandatory application of a standard within IFRS specific to entities with rate-regulated activities. The Exemptive Relief and the Companies Act Relief each replace similar exemptive relief that had been previously granted to Emera in 2014 and would have expired by January 1, 2019.

Preferred Shares

On May 31, 2018, Emera issued 12 million Cumulative Minimum Rate Reset First Preferred Shares, Series H at $25.00 per share at an initial dividend rate of 4.9 per cent. The aggregate gross and net proceeds from the offering were $300 million and $295 million, respectively. The net proceeds of the preferred share offering were used for general corporate purposes.

On July 6, 2018, Emera announced it would not redeem the 10,000,000 Cumulative Rate Reset First Preferred Shares, Series C Shares. The holders of the Series C Shares had the right, at their option, to convert all or any of their Series C Shares, on a one-for-one basis, into Cumulative Floating Rate First Preferred Shares, Series D of the Company on August 15, 2018 or to continue to hold their Series C Shares. On August 8, 2018, Emera announced that, after having taken into account all conversion notices received from holders, no First Preferred Shares, Series C Shares would be converted into Cumulative Floating Rate First Preferred Shares, Series D Shares.

Tampa Electric Big Bend Power Station Modernization

On May 24, 2018, Tampa Electric announced its intention to invest approximately $850 million USD to modernize the Big Bend Power Station. This modernization project includes conversion of Unit 1 from coal-fired to natural gas combined-cycle technology and the early retirement of Unit 2. This project has been initiated and is expected to be complete in 2023.

Tampa Electric Tax Reform and Storm Settlement

On March 1, 2018, the FPSC approved a settlement agreement filed by Tampa Electric that authorizes the utility to net the estimated amount of storm cost recovery against the return of estimated 2018 tax reform benefits to customers. Refer to the “Business Overview and Outlook – Emera Florida and New Mexico”, and “Financial Highlights – Emera Florida and New Mexico” sections for further details.

 

EMERA 2018 ANNUAL REPORT

31


MANAGEMENT’S DISCUSSION & ANALYSIS

 

 

NSPML

The Maritime Link entered service on January 15, 2018, enabling the transmission of electricity between Newfoundland and Nova Scotia. In Q1 2018, NSPML began recording cash earnings and collecting UARB approved cash payments from NSPI. Prior to Q1 2018, NSPML recorded non-cash AFUDC earnings as it was under construction. Refer to the “Business Overview and Outlook –Corporate and Other – ENL” section for further details.

APPOINTMENTS

Board of Directors

Effective July 10, 2018, James V. Bertram joined the Emera Board of Directors. Mr. Bertram is currently Chair of the Board, and former President and Chief Executive Officer, of Keyera Corporation, a publicly-traded, midstream oil and gas operator based in Calgary, Alberta.

Effective July 10, 2018, Jochen E. Tilk joined the Emera Board of Directors. 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.

OUTSTANDING COMMON STOCK DATA

 

Common stock

Issued and outstanding:

   millions of shares      millions of
Canadian dollars
 

 

Balance, December 31, 2016

     210.02        $        4,738  

Conversion of Convertible Debentures

     0.15        6  

Issuance of common stock

     14.61        680  

Issued under Purchase Plans at market rate

     3.89        182  

Discount on shares purchased under Dividend Reinvestment Plan

            (9

Options exercised under senior management stock option plan

     0.10        3  

Employee Share Purchase Plan

            1  

Balance, December 31, 2017

     228.77        $        5,601  

Conversion of Convertible Debentures

     0.01         

Issuance of common stock (1)

     0.45        22  

Issued under Purchase Plans at market rate

     4.87        200  

Discount on shares purchased under Dividend Reinvestment Plan

            (9

Options exercised under senior management stock option plan

     0.02        1  

Employee Share Purchase Plan

            1  

Balance, December 31, 2018

     234.12        $        5,816  
(1)

In Q1 2018, Emera issued 0.45 million common shares to facilitate the creation and issuance of 1.8 million depository receipts in connection with the ICDU share acquisition. The depository receipts are listed on the Bahamas International Securities Exchange.

As at February 12, 2019, the amount of issued and outstanding common shares was 234.2 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, 2018 was 234.9 million (2017 – 215.3 million). The weighted average shares of common stock outstanding – basic for the year ended December 31, 2018 was 233.0 million (2017 – 213.4 million).

 

EMERA 2018 ANNUAL REPORT

32


MANAGEMENT’S DISCUSSION & ANALYSIS

 

 

FINANCIAL HIGHLIGHTS

EMERA FLORIDA AND NEW MEXICO

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
 
     

 

2018

 

    

2017

 

   

2018

 

    

2017

 

 

Operating revenues – regulated electric

   $ 499      $ 470     $ 2,059      $ 2,048  

Operating revenues – regulated gas

     211        206       764        732  

Operating revenues – non-regulated

     3        4       13        13  

Total operating revenues

     713        680       2,836        2,793  

Regulated fuel for generation and purchased power

     145        143       610        634  

Regulated cost of natural gas

     91        84       300        292  

Adjusted contribution to consolidated net income – USD

   $ 77      $ 63     $ 331      $ 295  

Adjusted contribution to consolidated net income – CAD

   $ 101      $ 80     $ 428      $ 382  

Revaluation of US non-regulated deferred income taxes

   $      $ (221   $      $ (221

Contribution to consolidated net income – USD

   $ 77      $ (158   $ 331      $ 74  

Contribution to consolidated net income – CAD

   $ 101      $ (203   $ 428      $ 99  

Adjusted contribution to consolidated earnings per common share – CAD

   $ 0.43      $ 0.37     $ 1.84      $ 1.79  

Contribution to consolidated earnings per common share – CAD

   $ 0.43      $ (0.94   $ 1.84      $ 0.46  

Net income weighted average foreign exchange rate – CAD/USD

   $ 1.31      $ 1.28     $ 1.29      $ 1.34  

EBITDA – USD

   $ 244      $ 252     $ 998      $ 1,060  

EBITDA – CAD

   $       322      $       320     $       1,293      $       1,374  

2017 Revaluation of US Non-regulated Deferred Income Taxes

In Q4 2017, due to enactment of the US Tax Cuts and Jobs Act of 2017, Emera Florida and New Mexico recorded a $221 million USD non-cash income tax expense resulting from the provisional revaluation of existing US non-regulated net deferred income tax assets. No further adjustments were recognized in 2018 and the Company has completed its accounting for this revaluation. Management believes excluding this revaluation from adjusted net income better distinguishes the ongoing operations of the business, and allows investors to better understand and evaluate the Company.

 

EMERA 2018 ANNUAL REPORT

33


MANAGEMENT’S DISCUSSION & ANALYSIS

 

 

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 – 2017

     $        (158   $ 74  

Increased electric operating revenues – see Operating Revenues – Regulated Electric below

     29       11  

Increased gas operating revenues – see Operating Revenues – Regulated Gas below

     5       32  

(Increased) decreased fuel for generation and purchased power – see Regulated Fuel for Generation and Purchased Power below

     (2     24  

Increased cost of natural gas sold – see Regulated Cost of Natural Gas below

     (7     (8

Increased OM&G expenses due to Tampa Electric’s regulatory agreement to net storm costs and 2018 tax reform benefits resulting in storm costs recorded through OM&G, with the offsetting tax reform benefits recorded in income tax expense

     (31     (116

Increased depreciation and amortization due to asset growth and PGS’s regulatory agreement to net amortization of its MGP environmental regulatory asset and 2018 tax reform benefits. The offsetting tax reform benefits were recorded through income tax expense

     (6     (27

Increased other income as the result of higher AFUDC earnings due to the construction of the first tranche of solar and the Big Bend modernization project

     1       6  

Decreased income tax expense due to the reduction of the US federal corporate income tax rate, the amortization of deferred income tax regulatory liabilities and decreased income before provision for income taxes. A portion of this benefit is offset by the additional OM&G and amortization costs discussed above

     27       112  

Revaluation of US non-regulated deferred income taxes in 2017 due to tax reform

     221       221  

Other

     (2     2  

Contribution to consolidated net income – 2018

     $           77     $ 331  

Emera Florida and New Mexico’s CAD adjusted contribution to consolidated net income increased by $21 million to $101 million in Q4 2018, from $80 million in Q4 2017. For the year ended December 31, 2018, Emera Florida and New Mexico’s CAD adjusted contribution to consolidated net income increased $46 million to $428 million, from $382 million in 2017. These increases were primarily due to higher revenues as the result of customer growth, favourable weather in Florida and higher AFUDC earnings as a result of the completion of the first tranche of solar projects and the Big Bend modernization project at Tampa Electric.

The impact of the change in the foreign exchange rate increased CAD earnings for the quarter and year ended December 31, 2018, by $4 million and $1 million, respectively.

Emera Florida and New Mexico’s adjusted contribution to consolidated net income by area is summarized in the following table:

 

For the

millions of US dollars

    
Three months ended
December 31
 
 
           
Year ended
December 31
 
 
      2018     2017     2018     2017  

Tampa Electric

   $           64     $           57     $           294     $           274  

PGS

     11       12       47       43  

NMGC

     11       10       25       22  

Other (1)

     (9     (16     (35 )       (44

Adjusted contribution to consolidated net income

   $ 77     $ 63     $ 331     $ 295  

(1)   Other includes TECO Finance and administration costs.

        

Operating Revenues – Regulated Electric

Electric revenues increased $29 million to $499 million in Q4 2018, compared to $470 million in Q4 2017. For the year ended December 31, 2018, electric revenues increased $11 million to $2,059 million, from $2,048 million in 2017. Changes in both periods were primarily due to customer growth, favourable weather and higher rates related to the completion of the first tranche of solar projects. The year-over-year increase included an additional benefit to rates due to the completion of the Polk Power Station expansion.

 

EMERA 2018 ANNUAL REPORT

34


MANAGEMENT’S DISCUSSION & ANALYSIS

 

 

Electric revenues and sales volumes are summarized in the following tables by customer class:

 

Q4 Electric Revenues

 

millions of US dollars              
      2018      2017  

Residential

   $         265      $         237  

Commercial

     147        139  

Industrial

     40        39  

Other (1)

     47        55  

Total

   $ 499      $ 470  
(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”)              
      2018      2017  

Residential

     2,320        2,113  

Commercial

     1,568        1,503  

Industrial

     490        495  

Other

     486        489  

Total

     4,864        4,600  

Annual Electric Revenues

 

millions of US dollars              
      2018      2017  

Residential

   $         1,067      $         1,006  

Commercial

     582        578  

Industrial

     161        158  

Other (1)

     249        306  

Total

   $ 2,059      $ 2,048  
(1)

Other includes sales to public authorities, off-system sales to other utilities and regulatory deferrals related to clauses.

Annual Electric Sales Volumes

 

GWh              
      2018      2017  

Residential

     9,418        9,029  

Commercial

     6,266        6,362  

Industrial

     2,014        2,024  

Other

     2,219        2,010  

Total

     19,917        19,425  
 

 

Operating Revenues – Regulated Gas

Gas revenues increased $5 million to $211 million in Q4 2018, compared to $206 million in Q4 2017. For the year ended December 31, 2018, gas revenues increased $32 million to $764 million, from $732 million in 2017, due to higher clause recoveries, customer growth in Florida and favourable weather in Florida and New Mexico. This was partially offset by lower commodity costs in New Mexico.

Gas revenues and sales volumes are summarized in the following tables by customer class:

 

Q4 Gas Revenues

millions of US dollars              
      2018      2017  

Residential

   $         116      $     110  

Commercial

     61        60  

Industrial (1)

     9        9  

Other (2)

     25        27  

Total

   $ 211      $ 206  

 

(1)

Industrial includes sales to power generation customers.

(2)

Other includes off-system sales to other utilities and various other items.

Q4 Gas Sales Volumes

 

Therms (millions)              
      2018      2017  

Residential

     141        113  

Commercial

     214        202  

Industrial

     339        292  

Other

     72        53  

Total

     766        660  

Annual Gas Revenues

millions of US dollars              
      2018      2017  

Residential

   $         381      $       367  

Commercial

     226        220  

Industrial (1)

     37        35  

Other (2)

     120        110  

Total

   $ 764      $ 732  

 

(1)

Industrial includes sales to power generation customers.

(2)

Other includes off-system sales to other utilities and various other items.

Annual Gas Sales Volumes

 

Therms (millions)              
      2018      2017  

Residential

     389        344  

Commercial

     795        754  

Industrial

     1,338        1,216  

Other

     269        245  

Total

     2,791        2,559  
 

 

EMERA 2018 ANNUAL REPORT

35


MANAGEMENT’S DISCUSSION & ANALYSIS

 

 

Regulated Fuel for Generation, Purchased Power and Cost of Natural Gas

Electric Capacity

Tampa Electric is required to maintain a generating capacity greater than firm peak demand. The total Tampa Electric-owned generation capacity is 5,238 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

Regulated fuel for generation and purchased power increased $2 million to $145 million in Q4 2018, compared to $143 million in Q4 2017. For the year ended December 31, 2018, regulated fuel for generation and purchased power decreased $24 million to $610 million, compared to $634 million in 2017 primarily due to a change in generation mix to lower-cost natural gas and solar, from coal, oil and petcoke.

 

Q4 Production Volumes

     

GWh

     
      2018      2017  

Natural gas

     4,160        3,365  

Coal

     430        905  

Oil and petcoke

            228  

Solar

     68        9  

Purchased power

     495        171  

Total production volumes

         5,153          4,678  

 

Q4 Average Fuel Costs

 

     

US dollars

     
      2018      2017  

Dollars per Megawatt hour (“MWh”)

   $ 28      $ 31  

Annual Production

     

GWh

     
      2018      2017  

Natural gas

     16,097        13,685  

Coal

     3,088        5,089  

Oil and petcoke

     472        924  

Solar

     118        45  

Purchased power

     1,222        559  

Total production volumes

       20,997          20,302  

 

Annual Average Fuel Costs

 

     

US dollars

     
      2018      2017  

Dollars per MWh

   $ 29      $ 31  
 

 

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 stream 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.

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 to provide transportation-only services for all customer classes if requested. 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 $7 million to $91 million in Q4 2018, compared to $84 million in Q4 2017. For the year ended December 31, 2018, regulated cost of natural gas increased $8 million to $300 million, compared to $292 million in 2017. The increases were primarily due to higher sales volumes in Florida and New Mexico and higher commodity costs in Florida partially offset by lower commodity costs in New Mexico.

 

EMERA 2018 ANNUAL REPORT

36


MANAGEMENT’S DISCUSSION & ANALYSIS

 

 

Gas sales by type are summarized in the following tables:

 

Q4 Gas Sales Volumes by Type

     

Therms (millions)

     
      2018      2017  

System Supply

     242        194  

Transportation

     524        466  

Total

     766        660  

Annual Gas Sales Volumes by Type

     

Therms (millions)

     
      2018      2017  

System Supply

     745        671  

Transportation

     2,046        1,888  

Total

     2,791        2,559  
 

Gas sales volumes increased for the quarter and year ended December 31, 2018, primarily due to customer growth in Florida and favourable winter weather in Florida and New Mexico.

Regulatory Recovery Mechanisms

Tampa Electric

Fuel Recovery Clause

Tampa Electric has a fuel recovery clause approved by the FPSC, allowing it 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.

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 replenish the reserve.

PGS

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 based on 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. The FPSC approved a replacement program at a cost of approximately $80 million USD over a 10-year period. As part of the depreciation study settlement agreement approved by the FPSC in February 2017, the Cast Iron/Bare Steel clause was expanded to allow recovery of accelerated replacement of certain obsolete pipe.

 

EMERA 2018 ANNUAL REPORT

37


MANAGEMENT’S DISCUSSION & ANALYSIS

 

 

NMGC

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 the 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 the continued use of the PGAC is reasonable and necessary. In December 2016, NMGC received approval of its PGAC Continuation Filing for the four-year period ending December 2020.

NSPI

 

For the

millions of Canadian dollars (except per share amounts)

  

Three months ended
December 31

            

Year ended
December 31

 
     

 

2018

 

    

 

2017

 

    

 

2018

 

    

 

2017

 

 

Operating revenues – regulated electric

   $       385      $       355      $       1,440      $ 1,338  

Regulated fuel for generation and purchased power (1)

     179        141        639        477  

Contribution to consolidated net income

   $ 28      $ 23      $ 131      $ 129  

Contribution to consolidated earnings per common share – basic

   $ 0.12      $ 0.11      $ 0.56      $ 0.60  

EBITDA

   $ 126      $ 104      $ 498      $ 466  
(1)

Regulated fuel for generation and purchased power includes NSPI’s FAM and fixed cost deferrals on the Consolidated Income Statement, however it is excluded in the segment overview. The amounts excluded were $(19) million in Q4 2018 (2017 – $16 million) and $(46) million for the year ended December 31, 2018 (2017 – $59 million).

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 – 2017

     $            23       $          129  

Increased operating revenues – see Operating Revenues – Regulated Electric below

     30       102  

Increased fuel for generation and purchased power – see Regulated Fuel for Generation and Purchased Power below

     (38     (162

Decreased FAM and fixed cost deferrals due to a current year total under-recovery of fuel costs, compared to the prior year total over-recovery of fuel costs and the lower application of non-fuel revenues. Year-over-year was partially offset by the 2017 refund to customers of 2016 fuel costs

     35       105  

Increased OM&G expenses in 2018 primarily due to storm costs

     (7     (19

Increased depreciation and amortization due to increased property, plant and equipment

     (4     (12

Increased interest expense, net, year-over-year primarily due to higher average interest rate on the revolving credit facility and higher interest on the FAM regulatory deferral

     (4     (9

Increased income tax expense primarily due to change in tax reserve

     (8     (8

Other

     1       5  

Contribution to consolidated net income – 2018

     $            28       $          131  

NSPI’s contribution to consolidated net income increased $5 million to $28 million in Q4 2018 from $23 million in Q4 2017. For the year ended December 31, 2018, NSPI’s contribution to consolidated net income increased $2 million to $131 million from $129 million in 2017. These increases were the result of increased sales volume due to load growth and weather and decreased FAM and fixed cost deferral expense. This was partially offset by increased depreciation and amortization, OM&G and interest expenses.

 

EMERA 2018 ANNUAL REPORT

38


MANAGEMENT’S DISCUSSION & ANALYSIS

 

 

Operating Revenues – Regulated Electric

Operating revenues increased $30 million to $385 million in Q4 2018, compared to $355 million in Q4 2017. Revenues increased as a result increased sales volumes due to load growth and weather.

For the year ended December 31, 2018, operating revenues increased $102 million to $1,440 million, compared to $1,338 million in 2017. Revenues increased due to increased sales volume due to load growth and weather, the refund to customers of prior year over-recovery of fuel costs in 2017, and increased fuel related electricity pricing in 2018. This was partially offset by the Maritime Link assessment.

Electric revenues and sales volumes are summarized in the following tables by customer class:

 

Q4 Electric Revenues

millions of Canadian dollars                
     

2018

 

    

2017

 

 

Residential

 

  

 

$

 

 

199

 

 

 

 

  

 

$

 

 

178

 

 

 

 

Commercial

 

    

 

107

 

 

 

    

 

101

 

 

 

Industrial

 

    

 

62

 

 

 

    

 

56

 

 

 

Other

 

    

 

10

 

 

 

    

 

13

 

 

 

 

Total

 

  

 

$

 

 

378

 

 

 

 

  

 

$

 

 

348

 

 

 

 

Q4 Electric Sales Volumes              
GWh                
     

2018

 

    

2017

 

 

 

Residential

 

    

 

1,259

 

 

 

    

 

1,120

 

 

 

Commercial

 

    

 

799

 

 

 

    

 

771

 

 

 

Industrial

 

    

 

669

 

 

 

    

 

637

 

 

 

Other

 

    

 

76

 

 

 

    

 

85

 

 

 

Total

 

 

  

 

 

 

 

2,803

 

 

 

 

  

 

 

 

 

2,613

 

 

 

 

 

Annual Electric Revenues

millions of Canadian dollars                
     

2018

 

    

2017

 

 

Residential

 

  

 

$

 

 

731

 

 

 

 

  

 

$

 

 

679

 

 

 

 

Commercial

 

    

 

405

 

 

 

    

 

387

 

 

 

Industrial

 

    

 

233

 

 

 

    

 

200

 

 

 

Other

 

    

 

43

 

 

 

    

 

43

 

 

 

 

Total

 

  

 

$

 

 

1,412

 

 

 

 

  

 

$

 

 

1,309

 

 

 

 

Annual Electric Sales Volumes              
GWh                
     

2018

 

    

2017

 

 

 

Residential

 

    

 

4,581

 

 

 

    

 

4,374

 

 

 

Commercial

 

    

 

3,102

 

 

 

    

 

3,060

 

 

 

Industrial

 

    

 

2,611

 

 

 

    

 

2,466

 

 

 

Other

 

    

 

323

 

 

 

    

 

345

 

 

 

 

Total

 

  

 

 

 

 

10,617

 

 

 

 

  

 

 

 

 

10,245

 

 

 

 

 

Regulated Fuel for Generation and Purchased Power

Regulated fuel for generation and purchased power increased $38 million to $179 million in Q4 2018, compared to $141 million in Q4 2017. For the year ended December 31, 2018, regulated fuel for generation and purchased fuel power increased $162 million to $639 million, compared to $477 million in 2017. Changes in both periods were primarily due to the payment of the Maritime Link assessment, increased commodity prices, and increased sales volume.

NSPI’s FAM regulatory liability balance decreased $16 million from $177 million at December 31, 2017 to $161 million at December 31, 2018 primarily due to the net under-recovery of current period fuel costs and the refund to customers of the 2017 Maritime Link assessment. This was partially offset by the recovery in 2018 of the Maritime Link assessment to be refunded to customers as part of the assessment decision.

 

EMERA 2018 ANNUAL REPORT

39


MANAGEMENT’S DISCUSSION & ANALYSIS

 

 

Q4 Production Volumes              
GWh                
     

 

2018

 

    

 

2017

 

 

 

Coal

 

  

 

 

 

1,466

 

 

  

 

 

 

 

1,168

 

 

 

 

 

Natural gas

 

  

 

 

 

 

 

275

 

 

 

  

 

 

 

349

 

 

 

Oil and petcoke

 

  

 

 

 

 

254

 

 

 

 

  

 

 

 

 

352

 

 

 

 

 

Purchased power – other

 

  

 

 

 

 

175

 

 

 

 

  

 

 

 

 

220

 

 

 

 

 

Total non-renewables

 

  

 

 

 

 

2,170

 

 

 

 

  

 

 

 

 

2,089

 

 

 

 

 

Purchased power – IPP

 

  

 

 

 

 

369

 

 

 

 

  

 

 

 

 

374

 

 

 

 

 

Wind and hydro – renewables

 

  

 

 

 

 

318

 

 

 

 

  

 

 

 

 

190

 

 

 

 

 

Purchased power – Community Feed-in Tariff program (“COMFIT”)

 

  

 

 

 

 

153

 

 

 

 

  

 

 

 

 

158

 

 

 

 

 

Biomass – renewables

 

  

 

 

 

 

60

 

 

 

 

  

 

 

 

 

53

 

 

 

 

 

Total renewables

 

  

 

 

 

 

900

 

 

 

 

  

 

 

 

 

775

 

 

 

 

 

Total production volumes

 

  

 

 

 

 

3,070

 

 

 

 

  

 

 

 

 

2,864

 

 

 

 

Q4 Average Fuel Costs              
     

2018

 

    

2017

 

 

 

Dollars per MWh

 

    

 

$        58

 

 

 

    

 

$        49

 

 

 

Annual Production Volumes              
GWh                
     

 

2018

 

    

 

2017

 

 

 

Coal

 

  

 

 

 

 

4,930

 

 

 

 

  

 

 

 

 

4,839

 

 

 

 

 

Natural gas

 

  

 

 

 

 

1,427

 

 

 

 

  

 

 

 

 

1,444

 

 

 

 

 

Oil and petcoke

 

  

 

 

 

 

1,246

 

 

 

 

  

 

 

 

 

1,169

 

 

 

 

 

Purchased power – other

 

  

 

 

 

 

540

 

 

 

 

  

 

 

 

 

481

 

 

 

 

 

Total non-renewables

 

  

 

 

 

 

8,143

 

 

 

 

  

 

 

 

 

7,933

 

 

 

 

 

Purchased power – IPP

 

  

 

 

 

 

1,275

 

 

 

 

  

 

 

 

 

1,246

 

 

 

 

 

Wind and hydro – renewables

 

  

 

 

 

 

1,202

 

 

 

 

  

 

 

 

 

1,121

 

 

 

 

 

Purchased power – COMFIT

 

  

 

 

 

 

553

 

 

 

 

  

 

 

 

 

525

 

 

 

 

 

Biomass – renewables

 

  

 

 

 

 

189

 

 

 

 

  

 

 

 

 

153

 

 

 

 

 

Total renewables

 

  

 

 

 

 

3,219

 

 

 

 

  

 

 

 

 

3,045

 

 

 

 

Total production volumes

 

  

 

 

 

 

11,362

 

 

 

 

  

 

 

 

 

10,978

 

 

 

 

Annual Average Fuel Costs              
     

2018

 

    

2017

 

 

 

Dollars per MWh

 

    

 

$        56

 

 

 

    

 

$        43

 

 

 

 

 

Average fuel cost per MWh increased in Q4 2018 and for the year ended December 31, 2018, compared to 2017, due to payment of the Maritime Link assessment and increased commodity pricing.

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 PPAs in place. This results in the incremental cost of production generally increasing as sales volumes increase. Generation mix may also be affected by plant outages, availability of renewable generation, plant performance and compliance with environmental standards and regulations.

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.

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 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 an appropriate return to investors.

NSPI has a FAM, approved by the UARB, allowing NSPI to recover fluctuating fuel costs 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 FAM regulatory asset or liability and recovered from or returned to customers in a subsequent year.

 

EMERA 2018 ANNUAL REPORT

40


MANAGEMENT’S DISCUSSION & ANALYSIS

 

 

EMERA MAINE

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
 
     

 

2018

 

    

 

2017

 

    

 

2018

 

    

 

2017

 

 

Operating revenues – regulated electric

   $ 50      $ 55      $ 214      $ 228  

Regulated fuel for generation and purchased power (1)

     10        17        42        64  

Contribution to consolidated net income – USD

   $ 9      $ 7      $ 34      $ 36  

Contribution to consolidated net income – CAD

   $ 11      $ 8      $ 44      $ 46  

Contribution to consolidated earnings per common share – basic – CAD

   $       0.05      $       0.04      $       0.19      $ 0.22  

Net income weighted average foreign exchange rate – CAD/USD

   $ 1.32      $ 1.27      $ 1.30      $ 1.30  

EBITDA – USD

   $ 25      $ 23      $ 107      $ 107  

EBITDA – CAD

   $ 33      $ 29      $ 139      $ 139  
(1)

Regulated fuel for generation and purchased power includes transmission pool expenses.

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 – 2017

     $            7         $            36   

Decreased operating revenues – see Operating Revenues – Regulated Electric section below

     (5)        (14)  

Decreased regulated fuel for generation and purchased power – see Regulated Fuel for Generation and Purchased Power section below

            22   

Increased OM&G primarily due to increased storm restoration work, higher medical costs, and regulatory adjustments related to the distribution rate case, partially offset by higher capitalized construction overheads in 2018

     –         (8)  

Increased depreciation and amortization primarily due to increased regulatory amortization as a result of reduced purchase power contracts and higher plant in service

     (2)        (14)  

Decreased income tax expense primarily due to the reduction of the US federal corporate income tax rate and decreased income before provision for income taxes

            13   

Other

     –         (1)  

Contribution to consolidated net income – 2018

     $            9         $            34   

Emera Maine’s CAD contribution to consolidated net income increased by $3 million to $11 million in Q4 2018, from $8 million in Q4 2017. For the year ended December 31, 2018, Emera Maine’s CAD contribution to consolidated net income decreased $2 million to $44 million, from $46 million in 2017. The foreign exchange rate had minimal impact for the quarter and year ended December 31, 2018.

Operating Revenues – Regulated Electric

Operating revenues decreased $5 million to $50 million in Q4 2018, compared to $55 million in Q4 2017. For the year ended December 31, 2018, operating revenues decreased $14 million to $214 million in 2018, from $228 million in 2017. The year-over-year decrease was due to reduced transmission pool revenue primarily as a result of lower rates and lower stranded cost revenue primarily due to the expiration of a major purchased power contract. These decreases were partially offset by increased load due to favourable summer weather.

 

EMERA 2018 ANNUAL REPORT

41


MANAGEMENT’S DISCUSSION & ANALYSIS

 

 

Emera Maine’s operating revenues - regulated electric include sales of electricity and other services as summarized in the following table:

 

Q4 Operating Revenues – Regulated Electric

 

millions of US dollars              

 

 
     2018      2017    

 

 

Electric revenues

   $ 41      $ 41    

Transmission pool revenues

     8        10    

Resale of purchased power

     1        4    

 

 

Operating revenues – regulated electric

   $           50      $           55    

 

Annual Operating Revenues – Regulated Electric

 

millions of US dollars              

 

 
     2018      2017    

 

 

Electric revenues

   $ 165      $ 169    

Transmission pool revenues

     41        48    

Resale of purchased power

     8        11    

 

 

Operating revenues – regulated electric

   $         214      $         228    

 

 

 

Electric revenues and sales volumes are summarized in the following tables by customer class:    

 

Q4 Electric Revenues

 

millions of US dollars             

 

 
     2018     2017    

 

 

Residential

   $ 23     $ 21    

Commercial

     16       16    

Industrial

     3       2    

Other (1)

     (1     2    

 

 

Total

   $           41     $           41    

 

 

(1)

Other revenue includes amounts recognized relating to FERC transmission rate refunds and other transmission revenue adjustments.

Q4 Electric Sales Volumes

 

GWh              

 

 
     2018      2017    

 

 

Residential

               218        207    

Commercial

     192        194    

Industrial

     89        87    

Other

     3        3    

 

 

Total

     502                  491    

 

Annual Electric Revenues

 

millions of US dollars              

 

 
     2018      2017    

 

 

Residential

   $ 83      $ 81    

Commercial

     62        62    

Industrial

     12        12    

Other (1)

     8        14    

 

 

Total

   $         165      $         169    

 

 

(1)

Other revenue includes amounts recognized relating to FERC transmission rate refunds and other transmission revenue adjustments.

Annual Electric Sales Volumes

 

GWh              

 

 
     2018      2017    

 

 

Residential

     827        802    

Commercial

     769        773    

Industrial

     354        349    

Other

     12        14    

 

 

Total

             1,962                1,938    

 

 

 

Regulated Fuel for Generation and Purchased Power

Emera Maine’s regulated fuel for generation and purchased power decreased $7 million to $10 million in Q4 2018, compared to $17 million in Q4 2017. For the year ended December 31, 2018 regulated fuel for generation and purchased power decreased $22 million to $42 million, from $64 million in 2017 due to the expiration of a major purchased power contract.

2017 Revaluation of US Regulated Deferred Income Taxes

In Q4 2017, due to enactment of the US Tax Cuts and Jobs Act of 2017 Emera Maine recorded a $112 million USD non-cash provisional revaluation of existing US regulated net deferred income tax liabilities. Emera Maine recorded an equivalent increase of a regulatory liability as the impact of lower US taxes is expected to be returned to customers over time, as required by the Act or by order of the regulator. As a result, the deferred tax adjustment for Emera Maine had an impact on the 2017 balance sheet but no impact on 2017 earnings. No further adjustments were recognized in 2018 and the Company has completed its accounting for this revaluation.

Regulatory Recovery Mechanisms

Emera Maine’s distribution operations and stranded cost recoveries are regulated by the MPUC. The transmission operations are regulated by the FERC. Rates for these three elements are established in distinct regulatory proceedings.

 

EMERA 2018 ANNUAL REPORT

42


MANAGEMENT’S DISCUSSION & ANALYSIS

 

 

Emera Maine’s distribution businesses operate under a traditional cost-of-service regulatory structure, and distribution rates are set by the MPUC. For stranded cost recoveries, Emera Maine is permitted to recover all prudently incurred stranded costs resulting from the restructuring of the industry in 2000 that could not be mitigated or that arose as a result of rate and accounting orders issued by the MPUC. Emera Maine’s transmission businesses operate based on formulas utilizing prior year actual transmission investments and operating costs. Emera Maine collects revenue for its bulk transmission assets from ISO New England. Emera Maine is also required to contribute towards the total cost of the ISO New England pool transmission facilities on a ratable basis according to the proportion of the total New England load that their customers represent.

EMERA CARIBBEAN

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  

 

 

 
     2018     2017      2018     2017    

 

 

Operating revenues – regulated electric

   $ 90     $ 84      $ 360     $ 334    

 

 

Regulated fuel for generation and purchased power

     45       41        183       152    

 

 

Adjusted contribution to consolidated net income

   $ 11     $ 1      $ 35     $ 24    

 

 

Adjusted contribution to consolidated net income – CAD

   $ 14     $ 1      $ 45     $ 31    

 

 

After-tax equity securities mark-to-market gain (loss)

     (2            (3     –    

 

 

Contribution to consolidated net income

   $ 9     $ 1      $ 32     $ 24    

 

 

Contribution to consolidated net income – CAD

   $ 12     $ 1      $ 41     $ 31    

 

 

Adjusted contribution to consolidated earnings per common share – basic – CAD

   $ 0.06     $      $ 0.19     $ 0.15    

 

 

Contribution to consolidated earnings per common share – basic – CAD

   $ 0.05     $      $ 0.18     $ 0.15    

 

 

Net income weighted average foreign exchange rate – CAD/USD

   $       1.33     $       1.25      $       1.31     $       1.30    

 

 

Adjusted EBITDA

   $ 22     $ 11      $ 93     $ 87    

 

 

Adjusted EBITDA – CAD

   $ 30     $ 14      $ 121     $ 113    

 

 

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 – 2017

     $             1         $             24    

Increased operating revenues – see Operating Revenues – Regulated Electric below

            26    

Increased regulated fuel for generation and purchased power – see Regulated Fuel for Generation and Purchased Power below

     (4)        (31)   

Increased other income due to the 2017 impairment charge as a result of damage to Domlec’s assets from Hurricane Maria and the recognition of gains on the sale of investment securities in 2018 related to the BLPC self-insurance fund

            6    

Decreased OM&G costs due to operational cost savings at GBPC and BLPC quarter-over-quarter. Year-over-year, decreased OM&G due to operational cost savings at GBPC and lower maintenance at Domlec

            5    

Other

     (3)        2    

 

 

Contribution to consolidated net income – 2018

     $             9         $             32    

 

 

Emera Caribbean’s CAD contribution to consolidated net income increased $11 million to $12 million in Q4 2018, compared to $1 million in Q4 2017. For the year ended December 31, 2018, Emera Caribbean’s CAD contribution to consolidated net income increased $10 million to $41 million in 2018, compared to $31 million in 2017. These increases were primarily due to the impairment charge recognized in 2017, lower 2018 operating costs at GBPC and Domlec and gains on the sale of equity securities in 2018. The foreign exchange rate had minimal impact for the three months and year ended December 31, 2018.

 

EMERA 2018 ANNUAL REPORT

43


MANAGEMENT’S DISCUSSION & ANALYSIS

 

 

Operating Revenues – Regulated Electric

Operating revenues increased $6 million to $90 million in Q4 2018, compared to $84 million in Q4 2017. This increase reflected higher sales volumes at Domlec due to the impact of Hurricane Maria in 2017, increased fuel charge as a result of higher fuel prices in 2018 at BLPC and higher sales volumes at GBPC due to continued recovery from Hurricane Matthew.

For the year ended December 31, 2018, operating revenues increased $26 million to $360 million, compared to $334 million in 2017 due to increased fuel charge as a result of higher fuel prices in 2018 at BLPC, partially offset by lower sales volumes at Domlec in 2018 due to the impact of Hurricane Maria.

Electric revenues and sales volumes are summarized in the following tables by customer class:

 

Q4 Electric Revenues

 

millions of US dollars              

 

 
     2018      2017    

 

 

Residential

   $ 30      $ 27    

Commercial

     52        49    

Industrial

     6        6    

Other

     2        2    

 

 

Total

   $           90      $           84    

 

 
Q4 Electric Sales Volumes      
GWh              

 

 
     2018      2017    

 

 

Residential

     113        105    

Commercial

     186        182    

Industrial

     21        20    

Other

     4        4    

 

 

Total

               324                  311    

 

Annual Electric Revenues

 

millions of US dollars              

 

 
     2018      2017    

 

 

Residential

   $ 119      $ 110    

Commercial

     208        191    

Industrial

     23        23    

Other

     7        7    

 

 

Total

   $         357      $         331    

 

 
Annual Electric Sales Volumes      
GWh              

 

 
     2018      2017    

 

 

Residential

     446        462    

Commercial

               748                  753    

Industrial

     84        85    

Other

     15        17    

 

 

Total

     1,293        1,317    

 

 

 

Regulated Fuel for Generation and Purchased Power

Regulated fuel for generation and purchased power increased $4 million to $45 million in Q4 2018, compared to $41 million in Q4 2017 and for the year ended December 31, 2018, increased $31 million to $183 million compared to $152 million in 2017, primarily due to higher oil prices.

 

Q4 Production Volumes

 

GWh              

 

 
     2018      2017    

 

 

Oil

     335        334    

Hydro

     7        2    

Solar

     5        5    

Purchased Power

     7        5    

 

 

Total

               354                  346    

 

 
Q4 Average Fuel Costs      
     2018      2017    

 

 

Dollars per MWh

   $         127      $         119    

 

 

Annual Production Volumes

 

GWh            

 

     2018      2017  

 

Oil

     1,330      1,366  

Hydro

     24      27  

Solar

     18      18  

Purchased Power

                 26                  20  

 

Total

     1,398      1,431  

 

Annual Average Fuel Costs      
     2018      2017  

 

Dollars per MWh

   $         131      $        106  

 

 

 

Average fuel cost per MWh increased for the quarter and year-to-date, compared to 2017, due to higher oil prices.

 

EMERA 2018 ANNUAL REPORT

44


MANAGEMENT’S DISCUSSION & ANALYSIS

 

 

Regulatory Recovery Mechanisms

BLPC

BLPC’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. The FTC approves the calculation of the fuel charge, which is adjusted on a monthly basis.

GBPC

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.

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 over a five year period, 2017 to 2021, the all-in rate for electricity (fuel and base rates) will be held at 2016 levels. 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 7.8 per cent return on rate base and 50 per cent of amounts above 9.8 per cent return on rate base respectively.

Domlec

Substantially all of Domlec fuel costs flow through a fuel pass-through mechanism which provides the opportunity to recover prudently incurred fuel costs from customers in a timely manner.

EMERA ENERGY

 

For the

millions of Canadian dollars (except per share amounts)

           Three months ended
December 31
           

Year ended
December 31

      
              2018              2017             2018              2017       

Marketing and trading margin (1) (2)

   $          42      $          24     $          115      $          44    

Electricity and capacity sales (3)

              132                 115                445                 345      

Total operating revenues – non-regulated

              174                 139                560                 389      

Non-regulated fuel for generation and purchased power (4)

        68           65          238           214    

Adjusted contribution to consolidated net income

   $          44      $          26     $          120      $          24      

Revaluation of US non-regulated deferred income taxes

   $               $          12     $               $          12    

After-tax derivative mark-to-market gain (loss)

              67                 (48              45                 57      

Contribution to consolidated net income (loss)

   $          111      $          (10   $          165      $          93      

Adjusted contribution to consolidated earnings per common share – basic

   $          0.19      $          0.12     $          0.52      $          0.11      

Contribution to consolidated earnings per common share – basic

   $          0.47      $          (0.05   $          0.71      $          0.44      

Adjusted EBITDA

                        

Emera Energy Services

   $          33      $          20     $          85      $          25    

Emera Energy Generation

        34           34          125           66    

Equity Investment in Bear Swamp

              10                 7                32                 16      

Total

   $          77      $          61     $          242      $          107      

 

(1)

Marketing and trading margin represents Emera Energy Service’s purchases and sales of natural gas and electricity, pipeline capacity costs and energy asset management services’ revenues.

(2)

Marketing and trading margin excludes a pre-tax mark-to-market gain of $87 million in Q4 2018 (2017 – $37 million loss) and a gain of $16 million for the year ended December 31, 2018 (2017 – $119 million gain).

(3)

Electricity and capacity sales exclude a pre-tax mark-to-market gain of $10 million in Q4 2018 (2017 – $40 million loss) and a gain of $38 million for the year ended December 31, 2018 (2017 – $43 million loss).

(4)

Non-regulated fuel for generation and purchased power excludes a pre-tax mark-to-market of nil in Q4 2018 (2017 – $3 million gain) and a gain of $5 million for the year ended December 31, 2018 (2017 – $1 million loss).

 

EMERA 2018 ANNUAL REPORT

45


MANAGEMENT’S DISCUSSION & ANALYSIS

 

 

2017 Revaluation of US Non-regulated Deferred Income Taxes

In Q4 2017, due to enactment of the US Tax Cuts and Jobs Act of 2017, Emera Energy recorded a $12 million non-cash income tax recovery resulting from the provisional revaluation of existing US non-regulated net deferred income tax liabilities. No further adjustments were recognized in 2018 and the Company has completed its accounting for this revaluation. Management believes excluding this revaluation from adjusted net income better distinguishes the ongoing operations of the business, and allows investors to better understand and evaluate the Company.

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 northeastern 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 volatility 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.

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 – 2017

    $        (10)     $ 93   

Increased marketing and trading margin – see Emera Energy Services below

    18        71   

Increased electricity and capacity sales – see Emera Energy Generation below

    17        100   

Increased non-regulated fuel for generation and purchased power – see Emera Energy Generation below

    (3)       (24)  

Increased OM&G expenses due to increased performance-based compensation resulting from the increased marketing and trading margin; and the impact of an unplanned outage at Bridgeport Energy in 2017 that resulted in higher capitalization of maintenance spend compared to 2018

    (11)       (20)  

Increased income from equity investments mainly due to higher capacity prices at Bear Swamp in 2018

          15   

Increased income tax expense due to increased income before provision for income taxes, partially offset by the reduction of the US federal corporate income tax rate

    (5)       (41)  

Increased mark-to-market gain, net of tax quarter-over-quarter primarily due to changes in existing contract positions. Year-over-year decreased mark-to-market gain, net of tax due to a larger reversal of mark-to-market losses in 2017 compared to 2018 and change in existing contract positions, partially offset by lower amortization of gas transportation assets in 2018

    115        (12)  

Revaluation of US non-regulated deferred income taxes in 2017 due to tax reform

    (12)       (12)  

Other

    (2)       (5)  

Contribution to consolidated net income – 2018

    $        111      $ 165   

 

EMERA 2018 ANNUAL REPORT

46


MANAGEMENT’S DISCUSSION & ANALYSIS

 

 

Excluding the change in mark-to-market and the deferred tax revaluation in 2017, Emera Energy’s contribution to consolidated net income increased quarter-over-quarter due to the favourable impact of reduced maintenance on key pipelines in Q4 2018 on Emera Energy Services; and increased capacity prices for Emera Energy Generation. The year-over-year increase was also a result of the impact of favourable weather in 2018 on the business overall.

Emera Energy Services

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 related energy asset management services. EES is also responsible for commercial management of electricity production and fuel procurement for Emera Energy Generation’s fleet. 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 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 Margin

Marketing and trading margin increased $18 million to $42 million in Q4 2018, compared to $24 million in Q4 2017, which saw significant pipeline maintenance that reduced margins on hedged capacity.

Marketing and trading margin increased $71 million to $115 million in 2018, compared to $44 million in 2017. In addition to the Q4 2018 explanation above, this increase was due to the favourable impact of cold weather in early 2018 in several key market areas, which resulted in higher market prices and volatility that led to higher margins; and also provided favourable hedging opportunities for the first quarter of 2018. The impact of warmer summer weather in 2018 compared to 2017, also contributed to the increase.

Emera Energy Generation

Emera Energy wholly owns and operates a portfolio of high efficiency, non-utility electricity generating facilities in northeast North America. On November 26, 2018, Emera announced an agreement to sell its three New England Gas Generating facilities. The transaction is expected to close in the first quarter of 2019. Refer to the “Developments” section for further details.

Information regarding Emera Energy’s wholly owned generation facilities is summarized in the following table:

 

Wholly Owned

Generation Facilities

  Location    Capacity
(MW)
     Commissioning/
In-Service Date
     Fuel      Description

New England

                                   

Bridgeport

  Connecticut      560        1999        Natural gas      Selling electricity and capacity to ISO-NE

Tiverton

  Rhode Island      290        2000        Natural gas      Selling electricity and capacity to ISO-NE

Rumford

  Maine      265        2000        Natural gas      Selling electricity and capacity to ISO-NE

Total New England

         1,115                         

Maritime Canada

                                   

Bayside

  New Brunswick      290        2001        Natural gas     

Long-term PPA November – March; Selling electricity to Maritimes and ISO-NE for remainder of year; Selling capacity to ISO-NE

Brooklyn

  Nova Scotia      30        1996        Biomass      Long-term PPA

Total Maritime Canada

         320                         

Total EEG

         1,435                         

 

EMERA 2018 ANNUAL REPORT

47


MANAGEMENT’S DISCUSSION & ANALYSIS

 

 

For the portion of output not committed under PPAs, Emera Energy’s generation facilities sell into price-based competitive markets and earn revenues through the physical delivery of power and ancillary services, such as load regulation. The NEGG facilities also participate in the regional capacity market and are compensated for being available to provide power. The electricity generation business in the northeast is seasonal due largely to power demand and fuel prices which impact margins. Winter and summer are generally the strongest periods, reflecting colder weather and fewer daylight hours in the winter season, and cooling load in the summer; and the impact on margins of generally higher natural gas pricing in the winter months when it is also required for heating load.

Q4 Electricity and Capacity Sales

 

For the                                Three months ended  
millions of Canadian dollars                                            December 31  
              New England              Maritime Canada              Total  
      2018      2017      2018      2017      2018      2017  

Electricity sales

   $ 81      $ 78      $ 11      $ 9      $ 92      $ 87  

Capacity sales

     40        27               1        40        28  

Electricity and capacity sales

   $         121      $ 105      $         11      $ 10      $         132      $ 115  

Q4 Non-Regulated Fuel for Generation and Purchased Power

 

For the                                Three months ended  
millions of Canadian dollars                                            December 31  
              New England              Maritime Canada              Total  
      2018      2017      2018      2017      2018      2017  

Non-regulated fuel for generation and purchased power

   $           66      $ 63      $           2      $ 1      $           68      $ 64  

Annual Electricity and Capacity Sales

 

For the                                       Year ended  
millions of Canadian dollars                                            December 31  
              New England              Maritime Canada              Total  
      2018      2017      2018      2017      2018      2017  

Electricity sales

   $ 279      $ 209      $ 30      $ 53      $ 309      $ 262  

Capacity sales

     136        80               3        136        83  

Electricity and capacity sales

   $         415      $ 289      $         30      $ 56      $         445      $ 345  

Annual Non-Regulated Fuel for Generation and Purchased Power

 

For the                                       Year ended  
millions of Canadian dollars                                            December 31  
              New England              Maritime Canada              Total  
      2018      2017      2018      2017      2018      2017  

Non-regulated fuel for generation and purchased power

   $         226      $ 175      $         11      $ 35      $         237      $ 210  

Emera Energy evaluates electricity sales and non-regulated fuel for generation and purchased power on a combined basis (excluding Capacity sales) for its NEGG facilities because the sales price of electricity and the cost of natural gas used to generate it are highly correlated in that market. NEGG’s electricity sales net of non-regulated fuel for generation and purchased power was $15 million in Q4 2018 and Q4 2017.

NEGG’s electricity sales net of non-regulated fuel for generation and purchased power was $53 million in 2018, compared to $34 million in 2017. This increase of $19 million was due to the impact of an unplanned outage at Bridgeport Energy from mid-March 2017 to mid-June 2017 and higher realized electricity pricing in 2018 compared to 2017, reflecting more favourable market conditions, specifically the impact of weather.

 

EMERA 2018 ANNUAL REPORT

48


MANAGEMENT’S DISCUSSION & ANALYSIS

 

 

Capacity sales increased $12 million to $40 million in Q4 2018, compared to $28 million in Q4 2017; and increased $53 million to $136 million in 2018, compared to $83 million in 2017. These increases reflected higher capacity prices that came into effect for NEGG in June 2017 and June 2018.

The year-over-year reduction in electricity sales and non-regulated fuel for generation and purchased power in Maritime Canada in 2018, compared to 2017, reflected renegotiation of the Bayside Power PPA, providing increased dispatch flexibility, while maintaining the net revenue stream for the facility.

Operating Statistics

 

                 Three months ended      

For the

                                                   December 31      
      Sales Volumes (GWh) (1)      Plant Availability (%) (2)      Net Capacity Factor (%) (3)  
      2018      2017      2018      2017      2018      2017     

New England

     1,269        1,413        86.3%        94.9%        51.5%        57.4%    

Maritime Canada

     32        40        89.7%        77.8%        4.5%        5.6%    

Total

     1,301        1,453        87.0%        91.0%        41.0%        45.8%    

For the

                                                 
Year ended    
December 31    
 
 
      Sales Volumes (GWh) (1)      Plant Availability (%) (2)      Net Capacity Factor (%) (3)  
      2018      2017      2018      2017      2018      2017     

New England

     5,386        3,909        91.5%        81.8%        55.1%        40.0%    

Maritime Canada

     373        700        93.8%        73.0%        13.3%        25.0%    

Total

     5,759        4,609        92.0%        79.9%        45.8%        36.7%    

 

(1)

Sales volumes represent the actual electricity output of the plants.

(2)

Plant availability represents the percentage of time in the period that the plant was available to generate power regardless of whether it was running. Effectively, it represents 100 per cent availability reduced by planned and unplanned outages.

(3)

Net capacity factor is the ratio of the utilization of an asset as compared to its maximum capability, within a particular time frame. It is generally a function of plant availability and plant economics vis-à-vis the market.

NEGG sales volumes, plant availability and net capacity factor were lower quarter-over-quarter, reflecting more planned outage hours at the Bridgeport facility in Q4 2018. Year-over-year sales volumes, plant availability and net capacity factor were higher due to the impact of an unplanned outage at the Bridgeport facility from mid-March to mid-June 2017 and favourable market conditions in Q3 2018, compared to Q3 2017.

Maritime Canada plant availability was higher year-over-year due to a planned outage at the Bayside facility in Q2 2017. Sales volumes and capacity factor were lower due to negotiated changes to Bayside Power’s PPA.

 

EMERA 2018 ANNUAL REPORT

49


MANAGEMENT’S DISCUSSION & ANALYSIS

 

 

CORPORATE AND OTHER

 

For the

     Three months ended         Year ended  

millions of Canadian dollars (except per share amounts)

             December 31               December 31  
      2018     2017     2018     2017  

Operating revenues – regulated gas

   $ 16     $ 13     $ 57     $ 52  

Non-regulated operating revenue

     12       19       47       75  

Total operating revenue

   $ 28     $ 32     $ 104     $ 127  

Intercompany revenue (1)

     10       10       39       39  

Income from equity earnings

     21       26       109       96  

Interest expense, net (2)

     78       76       304       293  

Adjusted contribution to consolidated net income

   $ (31   $ (1   $ (97   $ (88

After-tax mark-to-market gain (loss)

     (1           (2     2  

Revaluation of US non-regulated deferred income taxes

           (46           (46

Contribution to consolidated net income (loss)

   $ (32   $ (47   $ (99   $ (132

Adjusted contribution to consolidated earnings per common share – basic

   $         (0.13)     $     $         (0.42)     $ (0.41)  

Contribution to consolidated earnings per common share – basic

   $ (0.14   $ (0.22   $ (0.42   $ (0.62

Adjusted EBITDA

   $ 13     $ 45     $ 131     $ 136  

 

(1)

Intercompany revenue consists of interest from Brunswick Pipeline, M&NP and EEG.

(2)

Interest expense, net excludes a pre-tax mark-to-market loss of $1 million in Q4 2018 (2017 – nil) and a loss of $2 million for the year-end December 31, 2018 (2017 – $3 million gain).

2017 Revaluation of US Non-regulated Deferred Income Taxes

In Q4 2017, due to enactment of the US Tax Cuts and Jobs Act of 2017, Corporate recorded a $46 million non-cash income tax expense resulting from the provisional revaluation of existing US non-regulated net deferred income tax assets. No further adjustments were recognized in 2018 and the Company has completed its accounting for this revaluation. Management believes excluding this revaluation from adjusted net income better distinguishes the ongoing operations of the business, and allows investors to better understand and evaluate the Company.

Net Income

Highlights of the net income changes are summarized in the following table:

 

For the

     Three months ended       Year ended  

millions of Canadian dollars

     December 31       December 31  

Contribution to consolidated net income (loss) – 2017

   $ (47   $ (132

Decreased non-regulated operating revenue due to less project activity at EUS

     (7     (28

Increased non-regulated direct costs quarter-over-quarter due to higher project costs in Q4 2018.

    

Decreased non-regulated direct costs year-over-year due to lower project activity at EUS

     (6     16  

Increased OM&G quarter-over-quarter due to timing of performance-based compensation

     (12     (1

Income from equity investments - see income from Equity Investments below

     (5     13  

Increased interest expense

     (2     (11

Increased income tax recovery year-over-year due to remeasurement of certain deferred tax balances as a result of a change in Florida state tax apportionment factors and increased losses before provision for income taxes, partially offset by the reduction of the US federal corporate income tax rate

     3       13  

Revaluation of US non-regulated deferred income taxes in 2017 due to tax reform

     46       46  

Increased preferred stock dividends due to the issuance of preferred shares in Q2 2018

           (7

Other

     (2     (8

Contribution to consolidated net income (loss) – 2018

   $ (32   $ (99

 

EMERA 2018 ANNUAL REPORT

50


MANAGEMENT’S DISCUSSION & ANALYSIS

 

 

Excluding the change in mark-to-market and the deferred tax revaluation in 2017, Corporate and Other’s costs increased for the quarter and year-over-year. The increase in Q4 2018 was due to timing of performance-based compensation and changes in project costs. The year-over-year increase was due to lower project activity at EUS, increased interest expense and increased preferred dividends, partially offset by increased income tax recovery and increased equity earnings from NSPML and LIL.

Income from Equity Investments

Income from equity investments are summarized in the following table:

 

For the
millions of Canadian dollars
   Three months ended
December 31
    

Year ended   

December 31   

 
      2018      2017      2018      2017    

M&NP

   $ 5      $ 6      $ 22      $ 23    

NSPML

     5        10        45        36    

LIL

     11        10        42        37    

Income from equity investments

   $             21      $     26      $     109      $     96    

In Q1 2018, NSPML began recording cash earnings and collecting UARB approved cash payments from NSPI. Prior to Q1 2018, NSPML recorded non-cash AFUDC earnings as it was under construction.

LIQUIDITY AND CAPITAL RESOURCES

The Company generates internally sourced cash from its various regulated and non-regulated energy investments and select asset sales. Utility customer bases are diversified by both sales volumes and rates 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 sufficient 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. Cash flows generated from the sale of select assets are dependent on the market for the assets, acceptable pricing and the timing of the close of any sales. 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.

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 expects to invest approximately $6.5 billion over the three-year period from 2019 to 2021 on rate base growth in the Company’s regulated utilities. Over 85 per cent of the investment is expected to be in Florida and Nova Scotia. Capital expenditures at the regulated utilities are subject to regulatory approval. Emera plans to use cash from operations, debt raised at the utilities and proceeds from the NEGG and other select asset sales to support normal operations, repayment of existing debt and capital requirements. Emera has credit facilities with varying maturities that cumulatively provide $3.1 billion of credit (refer to notes 22 and 24 in the consolidated financial statements for additional information regarding the credit facilities).

As a result of US tax reform, 2019 base rates have been adjusted in the majority of Emera’s US regulated utilities to reflect lower income tax expense and amortization of the deferred income tax regulatory liability recorded at the date of enactment. The resulting decrease in cash from operations will be partially offset by cash refunds associated with Alternative Minimum Tax (“AMT”) credits beginning in 2019.

Emera believes its liquidity is adequate given the Company’s expected operating cash flows, capital expenditures, and related financing plans.

 

EMERA 2018 ANNUAL REPORT

51


MANAGEMENT’S DISCUSSION & ANALYSIS

 

 

CONSOLIDATED CASH FLOW HIGHLIGHTS

Significant changes in the statements of cash flows between the years ended December 31, 2018 and 2017 include:

 

millions of Canadian dollars    2018     2017     $  Change  

Cash, cash equivalents and restricted cash, beginning of period

   $ 503     $ 491     $ 12  

Provided by (used in):

      

Operating cash flow before changes in working capital

     1,806       1,297       509  

Change in working capital

     (116     (104     (12

Operating activities

     1,690       1,193       497  

Investing activities

         (2,190         (1,761     (429

Financing activities

     344       593           (249

Effect of exchange rate changes on cash and cash equivalents

     25       (13     38  

Cash, cash equivalents and restricted cash, end of period

   $ 372     $ 503     $ (131

Cash Flow from Operating Activities

Net cash provided by operating activities for the year ended December 31, 2018 increased $497 million to $1,690 million, compared to $1,193 million in 2017.

Cash from operations before changes in working capital increased $509 million. This was due to lower under-recovery from customers on clause related costs in 2018 than 2017, and lower pension contributions in 2018 at Emera Florida and New Mexico, increased capacity payments at NEGG, and increased marketing and trading margin at EES. These were partially offset by increased fuel for generation and purchased power at NSPI.

Changes in working capital decreased operating cash flows by $12 million. This decrease was due to unfavourable changes in cash collateral at NSPI and unfavourable changes in inventory at NSPI reflecting increased fuel purchases. These were partially offset by favourable changes in accounts receivable and accounts payable at Emera Florida and New Mexico, and NSPI and favourable changes in cash collateral at Emera Energy.

Cash Flow Used in Investing Activities

Net cash used in investing activities increased $429 million to $2,190 million for the year ended December 31, 2018, compared to $1,761 million in 2017 due to an increase in capital expenditures, partially offset by reduced equity contributions in NSPML and LIL in 2018, compared to 2017.

Capital expenditures, including AFUDC and net of proceeds from disposal of assets, for the year ended December 31, 2018 were $2,178 million, compared to $1,537 million in 2017. Details of capital expenditures are shown below:

 

   

$1,567 million at Emera Florida and New Mexico (2017 – $914 million)

   

$350 million at NSPI (2017 – $393 million)

   

$103 million at Emera Maine (2017 – $85 million)

   

$87 million at Emera Caribbean (2017 – $72 million)

   

$33 million at Emera Energy (2017 – $47 million)

   

$38 million at Corporate and Other (2017 – $26 million)

Cash Flow from Financing Activities

Net cash provided by financing activities decreased $249 million to $344 million for the year ended December 31, 2018, compared to $593 million in 2017. The decrease was due to the issuance of common stock in 2017 and increased 2018 dividends on common stock. These were partially offset by the issuance of preferred stock in 2018, increased borrowings under Emera’s committed credit facilities in 2018, and a net increase of debt at Emera Florida and New Mexico.

 

EMERA 2018 ANNUAL REPORT

52


MANAGEMENT’S DISCUSSION & ANALYSIS

 

 

WORKING CAPITAL

As at December 31, 2018, Emera’s cash and cash equivalents were $316 million (2017 – $438 million) and Emera’s investment in non-cash working capital was $449 million (2017 – $322 million). Of the cash and cash equivalents held at December 31, 2018, $280 million was held by Emera’s foreign subsidiaries (2017 – $174 million). A portion of these funds are invested in countries that have certain exchange controls, required approvals, and processes for repatriation. Such funds remain available to fund local operating and capital requirements unless repatriated.

CONTRACTUAL OBLIGATIONS

As at December 31, 2018, commitments for each of the next five years and in aggregate thereafter consisted of the following:

 

millions of Canadian dollars    2019      2020      2021      2022      2023      Thereafter      Total   

Long-term debt principal

   $ 1,119      $ 898      $ 1,742      $ 758      $ 1,138      $ 9,847      $15,502  

Interest payment obligations (1)

     708        660        603        554        529        6,885      9,939  

Purchased power (2)

     204        203        209        208        209        2,194      3,227  

Transportation (3) (4)

     569        347        255        215        170        1,492      3,048  

Pension and post-retirement obligations (5)

     38        34        35        36        36        1,040      1,219  

Fuel and gas supply

     642        237        49        7        3             938  

Capital projects (6)

     524        147        45        11        3        8      738  

Long-term service agreements (7) (8)

     110        67        42        30        33        246      528  

Asset retirement obligations

     3        27        45        1        1        365      442  

Equity investment commitments (9)

            190                                  190  

Leases and other (10)

     18        15        10        9        7        75      134  

Demand side management

     44        1                                  45  

Long-term payable

     4        5        5        5        5             24  

Convertible debentures

                                        3      3  
     $     3,983      $     2,831      $     3,040      $     1,834      $     2,134      $     22,155      $    35,977  

 

(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, 2018, including any expected required payment under associated swap agreements.

(2)

Annual requirement to purchase electricity production from independent power producers or other utilities over varying contract lengths.

(3)

Purchasing commitments for transportation of fuel and transportation capacity on various pipelines.

(4)

Includes $82 million related to NEGG transportation capacity ($5 million in 2019; $5 million in 2020; $5 million in 2021; $4 million in 2022; $4 million in 2023 and $59 million thereafter). On completion of the sale of the NEGG facilities, the remaining future contractual obligations will be transferred to the buyer. Refer to “Developments” for additional information.

(5)

Defined benefit funding contractual obligations were determined based on funding requirements and assuming pension accruals cease as at December 31, 2018. Credited service and earnings are assumed to be crystallized as at December 31, 2018. The Company’s contractual obligations for post-retirement (non-pension) benefits assume members must be age 55 or over (50 for TECO Energy) as at December 31, 2018 to be eligible. As the defined benefit pension plans currently undergo regular reviews to revise contribution requirements and members are still accruing service under the plans, actual future contributions to the plans will differ from the amounts shown.

(6)

Includes $439 million of commitments related to Tampa Electric’s solar and Big Bend Power Station modernization projects.

(7)

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.

(8)

Includes $248 million related to various long-term service agreements NEGG has entered into for maintenance of certain generating equipment ($46 million in 2019; $9 million in 2020; $24 million in 2021; $16 million in 2022; $16 million in 2023 and $137 million thereafter). On completion of the sale of the NEGG facilities, the remaining future contractual obligations will be transferred to the buyer. Refer to “Developments” for additional information.

(9)

Emera has a commitment to make equity contributions to the Labrador Island Link Limited Partnership.

(10)

Operating lease agreements for office space, land, plant fixtures and equipment, telecommunications services, rail cars and vehicles.

NSPI has a contractual obligation to pay NSPML for the use of the Maritime Link over approximately 37 years. In January 2018, NSPI started paying the UARB approved interim assessment payments and, as of December 31, 2018, $96 million had been paid to NSPML. The UARB approved payment for 2019 is $111 million and is subject to a $10 million holdback. Refer to note 14 to the consolidated financial statements for the year ended December 31, 2018 for additional information. After 2019, the timing of and amounts payable to NSPML will be subject to regulatory filings with the UARB, with expected filings in 2019 and 2020.

 

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FORECASTED GROSS CONSOLIDATED CAPITAL EXPENDITURES    

2019 forecasted gross consolidated capital expenditures are as follows:    

 

millions of Canadian dollars    Emera Florida
and New Mexico
     NSPI      Emera
Maine
     Emera
Caribbean
     Emera
Energy
     Corporate
and Other
     Total     

Generation

       $ 509      $ 105      $      $ 96      $ 8      $      $ 718    

New renewable generation

     282                      16                      298    

Transmission

     68        60        33        2                      163    

Distribution

     323        125        32        33                      513    

Gas transmission and distribution

     479                                           479    

Facilities, equipment, vehicles, and other

     161        50        31        12               6        260    
         $ 1,822      $       340      $       96      $         159      $         8      $         6      $     2,431    

DEBT MANAGEMENT

In addition to funds generated from operations, Emera and its subsidiaries have, in aggregate; access to approximately $3.1 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 – Operating and acquisition credit facility

     June 2020 –Revolver      $ 900      $       411      $       489    

Emera Florida and New Mexico – in USD – credit facilities

     March 2019 –March 2022            1,500        871        629    

NSPI – Operating credit facility

     October 2023 – Revolver        600        518        82    

Emera Maine – in USD – Operating credit facility

     February 2023 –Revolver        80        24        56    

Other – in USD – Operating credit facilities

     Various        32        11        21    

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, 2018. Emera’s significant covenant is listed below:

 

      Financial Covenant    Requirement   

As at   

December 31, 2018   

Emera

        

Syndicated credit facilities

   Debt to capital ratio    Less than or equal to 0.70 to 1    0.60 : 1  

Recent financing activities for Emera and its subsidiaries are discussed below:

Emera

On May 31, 2018, Emera issued 12 million 4.90 per cent Cumulative Minimum Rate Reset First Preferred Shares, Series H at

$25.00 per share for gross proceeds of $300 million and net proceeds of $295 million. The net proceeds of the preferred share offering were used for general corporate purposes. For further details, refer to note 27 to the 2018 annual consolidated financial statements. The offering was made under Emera’s $750 million short form base shelf prospectus dated May 16, 2018. As at December 31, 2018, the Company has $450 million available for issuance under this prospectus, which expires on June 16, 2020.

Emera Florida and New Mexico

On October 4, 2018, TEC completed a $375 million USD 30-year senior notes issuance. The notes bear interest at a rate of 4.45 per cent and have a maturity date of June 15, 2049. On October 11, 2018 proceeds from this issuance were used to repay a $300 million USD 1-year term credit facility.

On June 7, 2018, TEC completed a $350 million USD 30-year senior notes issuance. The notes bear interest at a rate of

4.30 per cent and have a maturity date of June 15, 2048.

 

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On April 10, 2018, TECO Energy/Finance repaid a $250 million USD note upon maturity. The note was repaid using funds from existing credit facilities and cash on hand.

On March 23, 2018, TEC extended the maturity date of its $150 million USD accounts receivable collateralized borrowing facility from March 23, 2018 to March 22, 2021. There were no other changes in commercial terms.

On March 7, 2018, TECO Energy/Finance increased its $300 million USD revolving credit facility by $100 million USD to $400 million USD. There were no other changes in commercial terms.

On March 7, 2018, TECO Energy/Finance increased its $400 million USD term bank credit facility by $100 million USD to $500 million USD, and extended the maturity date from March 8, 2018 to March 8, 2019. There were no other changes in commercial terms.

NSPI

On October 31, 2018, NSPI amended its operating credit facility to extend the maturity from October 2021 to October 2023. There were no other changes in commercial terms.

Emera Maine

On November 15, 2018, Emera Maine completed a $50 million USD 30-year senior notes issuance. The notes bear interest at a rate of 4.71 per cent and will mature on November 15, 2048. Proceeds from this issuance were used for general corporate purposes.

On February 28, 2018, Emera Maine extended the maturity date of its $80 million USD operating credit facility from September 25, 2019 to February 28, 2023. There were no other changes in commercial terms.

ECI

On January 12, 2018, a wholly owned indirect subsidiary of ECI entered into a five year $18 million Bahamian dollar loan agreement with an interest rate of 4.00 per cent and maturity date of January 12, 2023.

EBP

On October 31, 2018, Emera Brunswick Pipeline amended its Credit Agreement to extend the maturity from February 2021 to February 2022. There were no other changes in commercial terms.

CREDIT RATINGS

Emera and its subsidiaries have been assigned the following senior unsecured debt ratings:

 

     S&P    Moody’s        DBRS   
Emera Inc.    BBB (Negative)    Baa3 (Negative)        N/A  
TECO Energy/TECO Finance    BBB (Negative)    Baa2 (Stable)        N/A  
TEC    BBB+ (Negative)    A3 (Stable)        N/A  
NMGC    BBB+ (Negative)    N/A        N/A  
NSPI    BBB+ (Negative)    N/A        A (low) (Stable)  

On December 21, 2018, DBRS Limited affirmed NSPI’s A (low) issuer and issue rating with a stable trend.

On December 19, 2018, Moody’s Investor Services affirmed Emera’s Baa3 (Negative) issuer rating and Emera US Finance LP’s Baa3 guaranteed senior unsecured rating. At the same time, Moody’s affirmed the Baa2 senior unsecured ratings of TECO Energy/TECO Finance and the A3 issuer and senior unsecured ratings of Tampa Electric Company, with a stable outlook.

On December 5, 2018, S&P Global Ratings affirmed its BBB+ long term corporate credit rating on Emera, NSPI, TECO Energy/ Finance, TEC and NMGC and changed its ratings outlook to negative from stable.

SHARE CAPITAL

As at December 31, 2018, Emera had 234.12 million (2017 – 228.77 million) common shares issued and outstanding. For the year ended December 31, 2018, 5.34 million common shares were issued (2017 – 18.6 million) for net proceeds of $215 million (2017 – $857 million).

As at December 31, 2018, Emera had 41 million preferred shares issued and outstanding (2017 – 29 million).

 

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MANAGEMENT’S DISCUSSION & ANALYSIS

 

 

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 five-year period for the plans. The cash required in 2019 for defined benefit pension plans is expected to be $53 million (2018 – $51 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 $33 million for 2019 (2018 – $31 million actual).

DEFINED BENEFIT PENSION PLAN SUMMARY

 

millions of Canadian dollars                            As at December 31, 2018  
Plans by region    TECO Energy
Pension Plans
     NSPI Pension
Plans
     Emera Maine
Pension Plans
     Caribbean
Plans
     Total    

Assets as at December 31, 2018

   $ 899      $ 1,220      $ 170      $ 11      $ 2,300    

Accounting obligation at December 31, 2018

     1,023        1,406        206        15        2,650    

Accounting expense during fiscal 2018

   $ 25      $ 40      $ 4      $ 1      $ 70    

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, 2018 totalled $759 million (2017 – $726 million). The securities are held in trust for an affiliate of the Province of Nova Scotia. Approximately 80 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 the following significant guarantees and letters of credit on behalf of third parties outstanding that are not included within the Consolidated Balance Sheets as at December 31, 2018:

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.

The Company has standby letters of credit and surety bonds in the amount of $67 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.

 

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Emera Reinsurance Limited has issued a standby letter of credit to secure its obligations under reinsurance agreements. The letter of credit expires in February 2019 and is renewed annually. The amount committed as of December 31, 2018 was $6 million USD.

Emera Inc., on behalf of NSPI, has a standby letter of credit to secure obligations under a supplementary retirement plan. The letter of credit expires in June 2019 and is renewed annually. The amount committed as at December 31, 2018 was $49 million.

DIVIDEND PAYOUT RATIO

Emera has provided annual dividend growth guidance of four to five per cent through 2021. 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 in the forecast period, it is expected to return to that range over time. Emera Incorporated’s common share dividends paid in 2018 were $2.2825 ($0.5650 in Q1, Q2, and Q3 and $0.5875 in Q4) per common share and $2.1325 ($0.5225 in Q1, Q2, and Q3 and $0.5650 in Q4) per common share for 2017, representing a payout ratio of 79 per cent of adjusted net income in 2018 and 86 per cent for 2017.

On August 9, 2018, Emera’s Board of Directors approved an increase in the annual common share dividend rate from $2.26 to $2.35. The first quarterly dividend payment at the increased rate was paid on November 15, 2018.

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 $21 million (2017 – nil) for the three months ended December 31, 2018 and $97 million for the year ended December 31, 2018 (2017 – nil). NSPML is accounted for as an equity investment and therefore, the corresponding earnings related to this revenue are reflected in Income from equity investments. Refer to the “Business Overview and Outlook – Corporate and Other – ENL” and “Contractual Obligations” sections for further details.

 

   

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 $7 million (2017 – $8 million) for the three months ended December 31, 2018 and $29 million for the year ended December 31, 2018 (2017 – $28 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, 2018 and at December 31, 2017.

ENTERPRISE RISK AND RISK MANAGEMENT

Emera has a business-wide risk management process, monitored by the Board of Directors, to ensure a 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 controlled within predetermined risk tolerances established through approved policies.

The Company’s risk management activities are focused on those areas that most significantly impact profitability, quality and consistency of income, and cash flow. In this section, Emera describes these 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.

 

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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. As cost-of-service utilities with an obligation to serve customers, Tampa Electric, PGS, NMGC, NSPI, Emera Maine, BLPC, GBPC, and Domlec must obtain regulatory approval to change rates and/or riders from their respective regulators. 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. In addition, the commercial and regulatory frameworks under which Emera and its subsidiaries operate can be impacted by changes in government and significant shifts in government policy including initiatives regarding deregulation or restructuring of the energy industry and shifts in policy which could occur as a result of climate change concerns. Emera’s investments in entities in which it has significant influence and which are subject to regulatory risk include NSPML, LIL, M&NP and Lucelec.

Deregulation or restructuring of the electric industry may result in increased competition and unrecovered costs that could adversely affect operations, net income and cash flows. Florida electric utilities, including Tampa Electric, have limited competition in their market for retail customers; however, there is currently a proposed constitutional initiative in Florida which, if passed, would grant customers of investor-owned utilities the right to choose their electricity provider and to generate and sell electricity, and would limit the business of investor-owned utilities to construction, operation and repair of electrical transmission and distribution systems. This initiative is going through the process for potential inclusion as an amendment to the Florida Constitution, to be voted on in November 2020. Such a vote would be subject to Florida Supreme Court approving the placing of the amendment on the ballot and conditional on the initiative attracting a sufficient number of petition signatures. In the event the amendment achieves the 60 per cent required votes, the implementing legislation would be required to be passed by no later than June 1, 2023 and with effect by no later than 2025.

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, fuel-related audits, rate filings and capital plans. The subsidiaries employ a collaborative regulatory approach through technical conferences and, where appropriate, negotiated settlements.

Brunswick Pipeline has a 25-year firm service agreement, expiring in 2034, with Repsol Energy Canada (“REC”). This firm service agreement was filed with the NEB, and provides for predetermined toll increases after the fifth and fifteenth year of the contract. As a regulated Group II pipeline, the tolls of Brunswick Pipeline are regulated by the NEB on a complaint basis. In the absence of a complaint, the NEB does not normally undertake a detailed examination of Brunswick Pipeline’s tolls.

WEATHER AND CLIMATE CHANGE RISK

The Company is subject to a number of risks that arise or may arise from weather and climate change, including seasonal variations, the risk of changes in regulations (refer to “Changes in Environmental Legislation” risk), more frequent and intense weather events, and warming air temperatures.

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. In the absence of a regulatory recovery mechanism for unanticipated resulting revenue losses, such events could have an effect on the results of operations, financial conditions or cash flows of the Company or its utilities.

Climate change is predicted to lead to increased frequency and intensity of weather events and related impacts such as storms, wildfires, flooding and storm surge. Extreme weather events create a risk of physical damage to the Company’s assets. High winds can damage 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 could adversely affect the operations of the Company’s hydro-electric facilities.

 

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The potential impacts of climate change, such as rising sea levels and larger storm surges from more intense hurricanes, can combine to produce greater damage to coastal located generation and other facilities. 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 generally 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 risk transfer.

Climate change is also characterized by increases in global air temperatures. Increased air temperatures may bring increased frequency and severity of wildfires, including within the Company’s service territories in the southern United States. Increased air temperatures could also result in decreased efficiencies over time of both generation and transmission facilities.

The increased 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 and 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.

CHANGES IN ENVIRONMENTAL LEGISLATION

Emera is subject to regulation by federal, provincial, state, regional and local authorities with regard to 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.

Beginning January 1, 2019, each province and territory in Canada is required to have a carbon pricing system which meets a benchmark set by the Government of Canada, failing which the Government of Canada would impose a carbon pricing system on each non-compliant province or territory equivalent to the federal benchmark. On October 23, 2018, the Government of Canada confirmed that the cap and trade carbon pricing system proposed by the Government of Nova Scotia met the federal benchmark. In the United States, the Environmental Protection Agency released a proposed rule to replace the Clean Power Plan, named the Affordable Clean Energy (“ACE”) rule. The ACE rule proposes to establish GHG emission guidelines for states to address GHG emissions from existing fossil fuel-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. 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 with the objective of complying 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 also in place to regularly test compliance.

 

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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 in order 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. 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, 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.

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, program maturity objectives and strategy derived, in part, on the National Institute of Standards and Technology’s Cyber Security Framework. 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.

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 the utilities provide and that they are addressed through regulations.

 

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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 uses foreign currency derivative instruments to hedge specific transactions. 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. 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 will be financed through internally generated cash flows, select asset sales, short-term credit facilities, and ongoing access to capital markets. Cash flows generated from the sale of select assets are dependent on the market for the assets, acceptable pricing and the timing of the close of any sales. The Company reasonably expects liquidity sources to exceed capital needs.

Emera’s access to capital and cost of borrowing is subject to a number of risk factors, including financial market conditions 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. Emera is subject to risk with changes in interest rates that could have an adverse effect on the cost of financing. Inability to access to cost-effective capital could have a material impact on Emera’s ability to fund its growth plan.

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, and liquidity. 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. Emera manages this risk 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, preferred share units and deferred share units.

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 into interest rate hedging contracts to limit its exposure to fluctuations in floating interest rate debt.

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.

 

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EMERA ENERGY MARKETING AND TRADING

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 process, 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. The Company’s commercial arrangements, including the combination of supply and purchase agreements, asset management agreements, pipeline transportation agreements and financial hedging instruments, as well as its credit policies, counterparty credit assessments, market and credit position reporting, and other risk management and reporting practices, are all used to manage and mitigate this risk.

EMERA ENERGY ELECTRICITY SALES AND NON-REGULATED FUEL FOR GENERATION AND PURCHASED POWER

Emera Energy’s natural gas fired plants in the northeastern United States, operating as merchant facilities, are susceptible to the volatility of the New England electricity market and natural gas prices. Market electricity prices are dependent upon a number of factors, including the projected supply and demand of electricity, natural gas prices, the price of other materials used to generate electricity, the cost of complying with applicable environmental and other regulatory requirements and weather conditions. A material change in any one of these factors can materially affect the profitability of the facilities. The Company takes a strategic approach to hedging the volatility of pricing risk in these markets. When market prices are favourable, the Company will typically enter into hedging instruments that effectively fix the price of natural gas and electricity.

On November 26, 2018, Emera announced an agreement to sell its three NEGG facilities. The transaction is expected to close in the first quarter of 2019. Refer to the “Developments” section for further details.

COUNTERPARTY 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 specific accounts.

COUNTRY RISK

Earnings outside of Canada constituted 69 per cent (65 per cent from the US and 4 per cent from the Caribbean) of Emera’s earnings in 2018 (2017 – 42 per cent, with 35 per cent from the US and 7 per cent from the Caribbean). 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 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.

COMMERCIAL RELATIONSHIPS RISK

The Company is exposed to commercial relationships risk in respect of its reliance on certain key partners, suppliers and customers. The Company manages commercial relationship risk by monitoring credit risk, as discussed above in Counterparty Credit Risk, and monitoring of significant developments with its customers, partners and suppliers.

 

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COMMODITY PRICE RISK

A large portion of the Company’s fuel supply comes from international suppliers and is subject to commodity price risk. The Company manages this risk through established processes and practices to identify, monitor, report and mitigate these risks. Fuel contracts 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 through the use of financial hedging instruments and physical contracts and through contractual protection with counterparties, where applicable. In addition, the adoption and implementation of fuel adjustment mechanisms in its rate-regulated subsidiaries has further helped manage this risk, as the regulatory framework for the Company’s rate-regulated subsidiaries permits the recovery of prudently incurred fuel costs.

FUTURE EMPLOYEE BENEFIT PLAN PERFORMANCE AND FUNDING RISK

Emera subsidiaries have both defined benefit and defined contribution employee benefit plans that cover their employees and retirees. All defined benefit plans are closed to new entrants, with the exception of 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. 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 3 to 5 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 40 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.

 

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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 manages this risk through regular IT asset lifecycle management, dedicated project teams, executive oversight and appropriate governance structures and strong project management practices. Employees with extensive subject matter expertise assist in planning, project management, implementation and training. Formal back up and critical incident response practices ensure that continuity is maintained in the event of any disruptions or incidents.

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 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. 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 of 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. 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.

 

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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 and updating a “Risk Dashboard” for the Board of Directors on a quarterly basis. Furthermore, a corporate team independent from operations is responsible for tracking and reporting on market and credit risks.

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. 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 effective portion of 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. Any ineffective portion of the change in the fair value of the cash flow hedges is recognized in net income in the reporting period.

Where the documentation or effectiveness requirements are not met, the derivatives are recognized at fair value, with any changes in fair value recognized in net income in the reporting period, unless deferred as a result of regulatory accounting.

Derivatives entered into by Tampa Electric, PGS, 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. 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 realized gain or loss is recognized when the hedged item settles 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.

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
2018
    December 31
2017
 

Derivative instrument assets (current and other assets)

   $     $ 7  

Derivative instrument liabilities (current and long-term liabilities)

     (5     (7

Net derivative instrument assets (liabilities)

   $ (5   $  

 

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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

 
      2018      2017  

Operating revenues - regulated

   $                 5        $            (10)  

Non-regulated fuel for generation and purchased power

     1         

Effective net gains (losses)

   $ 6        $              (7)  

The effective net gains (losses) reflected in the above table would be 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
2018
    December 31
2017
 

Derivative instrument assets (current and other assets)

   $       104     $             181  

Regulatory assets (current and other assets)

     6       13  

Derivative instrument liabilities (current and long-term liabilities)

     (6     (13

Regulatory liabilities (current and long-term liabilities)

     (115     (183

Net asset (liability)

   $ (11   $ (2

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
 
      2018      2017  

Regulated fuel for generation and purchased power (1)

   $                 11      $                 17  

Net gains (losses)

   $ 11      $ 17  

 

(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 or property plant and equipment will be recognized in “Regulated fuel for generation and purchased power” when the hedged item is consumed.

 

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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
2018
   

December 31

2017

 

Derivative instruments assets (current and other assets)

   $ 62     $ 63  

Derivative instruments liabilities (current and long-term liabilities)

     (354     (290 )   

Net derivative instrument assets (liabilities)

   $ (292   $ (227 )   

HELD-FOR-TRADING 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   

 
      2018           2017    

Non-regulated operating revenues

   $           193        $ 408    

Non-regulated fuel for generation and purchased power

     2            12    

Net gains (losses)

   $ 195          $ 420    

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
2018
   

December 31   

2017   

 

Derivative instrument assets (current and other assets)

   $ 1     $ 2    

Net derivative instrument assets (liabilities)

   $ 1     $ 2    

OTHER DERIVATIVES RECOGNIZED IN NET INCOME

The Company recognized in net income the following gains (losses) related to other derivatives:

 

For the

millions of Canadian dollars

               Year ended   
December 31   
 
      2018          2017    

Interest expense, net

     $               (1)        $ 2    

Total gains (losses)

     $               (1)        $ 2    

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, 2018 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 quarter ended December 31, 2018, that have materially affected, or are reasonably likely to materially affect, the Company’s internal control over financial reporting.

 

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CRITICAL ACCOUNTING ESTIMATES

The preparation of consolidated financial statements in accordance with generally accepted accounting principles requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting periods. Management evaluates the Company’s estimates on an ongoing basis based upon historical experience, current conditions and assumptions believed to be reasonable at the time the assumption is made.

Significant areas requiring the use of management estimates relate to rate-regulated assets and liabilities, pension and post-retirement benefits, unbilled revenue, useful lives for depreciable assets, goodwill and long-lived assets impairment assessments, income taxes, asset retirement obligations, capitalized overhead and valuation of financial instruments. 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. The 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 $1,569 million (2017 - $1,411 million) of regulatory assets and $2,610 million (2017 - $2,468 million) of regulatory liabilities as at December 31, 2018.

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. The 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 $955 million at December 31, 2018 (2017 - $894 million).

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 experience.

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. 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 the annual pension funding requirements. This could have a significant impact on the Company’s annual 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 7.5 years for the Canadian plans and a weighted average of 12.4 years for the US plans). The Company’s use of smoothed asset values reduces the 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.

 

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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:

 

              2018              2017     
     

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

     3.63%        6.85%        4.16%        7.00%    

TECO Energy Group Supplemental Executive
Retirement Plan (1)

     3.11%   /  3.84%        N/A        3.37%  /   3.25%        N/A    

TECO Energy Group Benefit Restoration Plan (1)

     3.26%  /  3.76%   /  4.01%        N/A        3.64%        N/A    

TECO Energy Post-retirement Health and Welfare Plan

     3.70%        N/A        4.28%        N/A    

New Mexico Gas Company Retiree Medical Plan

     3.71%        4.00%        4.29%        7.00%    

NSPI

     3.50%        6.00%        3.84%        6.00%    

Bangor Hydro (2)

     3.53%        6.55%        4.04%        6.55%    

Maine Public Service (2)

     3.45%        6.55%        3.91%        6.55%    

GBPC Salaried

     4.25%        6.00%        4.25%        6.00%    

GBPC Union

     5.00%        5.00%        5.00%        5.00%    

 

(1)

The discount rate for benefit cost purposes is updated throughout the year as special events occur, such as settlements and curtailments.

(2)

Effective January 1, 2014, Bangor Hydro Electric Company and Maine Public Service Company merged to become Emera Maine.

Based on management’s estimate, the reported benefit cost for defined benefit and defined contribution plans was $115 million in 2018 (2017 - $105 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 2018 benefit cost of $9 million and $6 respectively (2017 - $9 million and $6 million).

UNBILLED REVENUE

Electric revenues are billed on a systematic basis over a one or two-month period for NSPI and a one-month period for Tampa Electric, PGS, NMGC, Emera Maine, BLPC, GBPC and Domlec. 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, 2018, unbilled revenues totalled $296 million (2017 - $278 million) on total annual operating revenues of $6,524 million (2017 - $6,226 million).

PROPERTY, PLANT AND EQUIPMENT

Property, plant and equipment represents 58 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. 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 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 formal depreciation studies and require the appropriate regulatory approval. Depreciation expense was $881 million for the year ended December 31, 2018 (2017 - $833 million).

 

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GOODWILL IMPAIRMENT ASSESSMENTS

Goodwill is subject to an annual assessment for impairment at the reporting unit level. 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. 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 an entity 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 an entity 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 of a reporting unit include discount and growth rates, rate case assumptions, valuation of net operating losses, utility sector market performance and transactions, projected operating and capital cash flows for the relevant business and the fair value of debt.

At December 31, 2018, the Company had goodwill with a total carrying amount of $6,313 million (December 31, 2017 – $5,805 million). The change in the carrying value from 2017 to 2018 was a result of the strengthening US dollar on the goodwill balances. This goodwill represents the excess of the acquisition purchase price for TECO Energy (Tampa Electric, PGS and NMGI reporting units), Emera Maine and GBPC over the fair values assigned to individual assets acquired and liabilities assumed.

The fair market value of goodwill 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, Emera Maine 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.

No impairment provisions with respect to goodwill were required for either 2018 or 2017.

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 such indicators exist. The Company reviews all long-lived assets in the last quarter of each year to ensure that any gradual change over the year and the seasonality of the markets are considered when determining which assets require an impairment analysis. In the case of a triggering event, such as a significant market disruption or sale of a business, the values of related long-lived assets are reviewed outside of this annual analysis. 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 believes accounting estimates related to asset impairments are critical estimates for the following reasons: 1) the estimates are highly susceptible to change, as management is required to make assumptions based on expectations of the results of operations for significant/indefinite future periods and/or the current market conditions in such periods; 2) markets can experience significant uncertainties; 3) the estimates are based on the ongoing expectations of management regarding probable future uses and holding periods of assets; and 4) the impact of an impairment on reported assets and earnings could be material. 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.

No material impairment provisions with respect to long-lived assets were required for 2018 or 2017.

 

EMERA 2018 ANNUAL REPORT

70


MANAGEMENT’S DISCUSSION & ANALYSIS

 

 

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 the application of tax statutes and regulations and the outcomes of tax audits and appeals requires 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 the issuance of relevant guidance by the courts or tax authorities and developments occurring in the examinations of the Company’s tax returns.

The Company believes the accounting estimate related to income taxes is a critical estimate for the following reasons:

1) realization of deferred tax assets is dependent upon the generation of sufficient taxable income, both operating and capital, in future periods; 2) a change in the estimated valuation allowance could have a material impact on reported assets and results of operations; and 3) 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 our estimate of income taxes, including the potential for elimination or reduction of our ability to realize tax benefits and to utilize deferred tax assets.

In response to the US enactment of the Tax Cuts and Jobs Act on December 22, 2017, Emera recorded an $813 million net revaluation of the Company’s US deferred tax assets and liabilities at December 31, 2017. Management estimated the implications of the Act based on the best information available. No further adjustments were recorded in 2018 and the Company has completed its accounting for the revaluation of its US deferred income tax assets and liabilities resulting from the effects of the Act. The Company believes that its US based financing interest will be deductible under the Act. Any change in assumptions could have a material impact on the results of the Company. Refer to “Significant Items Affecting Earnings - US Tax Reform” for further details.

ASSET RETIREMENT OBLIGATIONS (“ARO”)

The 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 and 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”. 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, 2018, the AROs recorded on the balance sheet were $205 million (2017 – $172 million). The Company estimates the undiscounted amount of cash flow required to settle the obligations is approximately $451 million (2017 – $438 million), which will be incurred between 2019 and 2061. The majority of these costs will be incurred between 2028 and 2050.

 

EMERA 2018 ANNUAL REPORT

71


MANAGEMENT’S DISCUSSION & ANALYSIS

 

 

CAPITALIZED OVERHEAD

As required by their respective regulators, Emera’s rate regulated subsidiaries and regulated equity investments capitalize overhead costs that are attributable to the overall capital expenditure program. The methodology for the calculation of capitalized overhead is approved by the respective regulators. For the year ended December 31, 2018, $187 million of overhead costs (2017 – $156 million) were capitalized to capital assets. Any change in the methodology for the calculation and allocation of overhead costs could have a material impact on the amounts recognized as expenses versus assets.

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 the 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 unobservable 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 contracts in which the terms 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 2018, are described as follows:

RECLASSIFICATION OF CERTAIN TAX EFFECTS FROM ACCUMULATED OTHER COMPREHENSIVE INCOME

In February 2018, the Financial Accounting Standards Board (“FASB”) issued Accounting Standard Updates (“ASU”) No. 2018-02,

Income Statement – Reporting Comprehensive Income (Topic 220): Reclassification of Certain Tax Effects from Accumulated Other Comprehensive Income. The standard allows reclassification from accumulated other comprehensive income to retained earnings for certain tax effects resulting from the US Tax Cuts and Jobs Act that would otherwise be stranded in accumulated other comprehensive income. This guidance is effective for annual reporting periods, including interim reporting within those periods, beginning after December 15, 2018, with early adoption permitted. The Company early adopted the standard in Q2 2018 and elected to not reclassify tax effects resulting from the US Tax Cuts and Jobs Act stranded in accumulated other comprehensive income to retained earnings as amounts were not material. Emera utilizes a portfolio approach to determine the timing and extent to which stranded income tax effects from items that were previously recorded in accumulated other comprehensive income are released.

REVENUE FROM CONTRACTS WITH CUSTOMERS

On January 1, 2018, the Company adopted ASU 2014-09, Revenue from Contracts with Customers and all the related amendments, which created a new, principle-based revenue recognition framework. The standard has been codified as Accounting Standards Codification (“ASC”) Topic 606. The core principle is that a company should recognize revenue when it transfers promised goods or services to customers in an amount that reflects the consideration to which the company expects to be entitled to. The guidance requires additional disclosures regarding the nature, amount, timing and uncertainty of revenue and related cash flows arising from contracts with customers. This guidance is effective for annual reporting periods, including interim reporting within those periods, beginning after December 15, 2017.

The Company adopted ASC 606 using the modified retrospective method. Results for reporting periods beginning after January 1, 2018 are presented under Topic 606, while prior period amounts are not adjusted and continue to be reported in accordance with historic accounting practices. The adoption of ASC 606 resulted in no adjustments to the Company’s opening retained earnings as of the adoption date. The impact of the adoption of the new standard was immaterial to the Company’s net income and is expected to be immaterial on an ongoing basis.

 

EMERA 2018 ANNUAL REPORT

72


MANAGEMENT’S DISCUSSION & ANALYSIS

 

 

RECOGNITION AND MEASUREMENT OF FINANCIAL ASSETS AND FINANCIAL LIABILITIES

On January 1, 2018, the Company adopted ASU 2016-01, Financial Instruments – Recognition and Measurement of Financial Assets and Financial Liabilities and all of the related amendments. The standard provides guidance for the recognition, measurement, presentation and disclosure of financial assets and liabilities. This guidance is effective for annual reporting periods, including interim reporting within those periods, beginning after December 15, 2017.

The standard requires investments in equity securities, except those accounted for under the equity method of accounting or those that result in consolidation, to be measured at fair value. The Company has elected to measure equity securities that do not have a readily determinable fair value at cost minus impairment (if any), plus or minus observable price changes resulting from transactions for the identical or similar investments of the same issuer. The standard eliminates the available-for-sale classification for equity investments that recognized changes in the fair value as a component of other comprehensive income, resulting in all changes in fair value being recognized in net income. The impact as a result of the remeasurement of equity investments is expected to be immaterial to the Company’s net income on an ongoing basis. A cumulative-effect adjustment of $4 million was made which increased retained earnings in the Consolidated Balance Sheet as of January 1, 2018.

CLARIFYING THE DEFINITION OF A BUSINESS

In January 2017, the FASB issued ASU 2017-01, Clarifying the Definition of a Business. The standard provides guidance to assist entities with evaluating when a set of transferred assets and activities is a business. This guidance is effective for annual reporting periods, including interim reporting within those periods, beginning after December 15, 2017 and is required to be applied prospectively. The Company adopted ASU 2017-01 effective January 1, 2018. There was no impact on the consolidated financial statements as a result of the adoption of this standard.

IMPROVING THE PRESENTATION OF NET PERIODIC PENSION COST AND NET PERIODIC POSTRETIREMENT BENEFIT COST

In March 2017, the FASB issued ASU 2017-07, Compensation – Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost. The guidance requires the service cost component of defined benefit pension or other postretirement benefit plans to be reported in the same line items as other compensation costs. The other components of net benefit cost are required to be presented in the Consolidated Statements of Income outside of income from operations. Only the service cost component is eligible for capitalization as property, plant and equipment under this guidance. This guidance is effective for annual reporting periods, including interim reporting within those periods, beginning after December 15, 2017. The guidance is required to be applied retrospectively for presentation in the Consolidated Statements of Income and prospectively for the guidance around capitalization.

The Company adopted ASU 2017-07 effective January 1, 2018 and December 31, 2017 balances have been retrospectively restated in the Consolidated Statements of Income. The standard allows the Company to use the amounts disclosed in its pension and other postretirement benefit plan note for the prior comparative periods as the estimation basis for applying the retrospective presentation requirements. This change resulted in $27 million of costs, previously presented within “Operating, maintenance and general”, being reclassified to “Other income (expense), net” in the Consolidated Statements of Income for the year ended December 31, 2017.

 

EMERA 2018 ANNUAL REPORT

73


MANAGEMENT’S DISCUSSION & ANALYSIS

 

 

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 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.

LEASES

In February 2016, the FASB issued ASU 2016-02, Leases. The standard, codified as ASC Topic 842, increases transparency and comparability among organizations by recognizing lease assets and liabilities on the balance sheet for leases with terms of more than 12 months. Under the previous guidance, operating leases are not recorded as assets and liabilities on the balance sheet. The effect of leases on the Consolidated Statements of Income and the Consolidated Statements of Cash Flows is largely unchanged. The guidance will require additional disclosures regarding key information about leasing arrangements. This guidance is effective for annual reporting periods, including interim reporting within those periods, beginning after December 15, 2018. Early adoption is permitted and is required to be applied using a modified retrospective approach. The Company will not early adopt the standard.

In January 2018, the FASB issued an amendment to ASC Topic 842 that permits companies to elect to not evaluate existing land easements under the new standard if the land easements were not previously accounted for under existing lease guidance. The Company will make this election. In July 2018, the FASB issued an amendment to ASC Topic 842 that permits companies to elect not to restate their comparative periods in the period of adoption when transitioning to the standard. The Company will make this election. Additionally, the Company will elect the options that allow the Company to not reassess whether any expired or existing contracts contain leases, carry forward existing lease classification, use hindsight to determine the lease term for existing leases and not separate lease components from non-lease components for all lessee and lessor arrangements.

Over the past several years, the Company developed and executed a project plan which included holding training sessions with key stakeholders throughout the organization, gathering detailed information on existing lease arrangements, evaluating implementation alternatives and calculating the lease asset and liability balances associated with individual contractual arrangements. The Company has implemented additional processes and controls to facilitate the identification, tracking and reporting of potential leases based on the requirements of the standard. Updates to systems are not required as a result of implementation of this standard. The adoption of this standard will affect the Company’s financial position by increasing assets and liabilities related to operating leases by approximately $70 million, with no impact to the Company’s Consolidated Statements of Income. There will be no significant changes to the Company’s accounting for lessor arrangements as a result of the adoption of the standard. The Company is in the process of assessing the disclosure requirements and continues to monitor FASB amendments to ASC Topic 842.

MEASUREMENT OF CREDIT LOSSES ON FINANCIAL INSTRUMENTS

In June 2016, the FASB issued ASU 2016-13, Measurement of Credit Losses on Financial Instruments. 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, including 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.

This guidance will be effective for annual reporting periods, including interim reporting within those periods, beginning after December 15, 2019. Early adoption is permitted for annual reporting periods, including interim periods after December 15, 2018 and will be applied using a modified retrospective approach. The Company is currently evaluating the impact of adoption of this standard on its consolidated financial statements.

 

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74


MANAGEMENT’S DISCUSSION & ANALYSIS

 

 

TARGETED IMPROVEMENTS TO ACCOUNTING FOR HEDGING ACTIVITIES

In August 2017, the FASB issued ASU 2017-12, Targeted Improvements to Accounting for Hedging Activities, which amends the hedge accounting recognition and presentation requirements in ASC Topic 815. This standard improves the transparency and understandability of information about an entity’s risk management activities by better aligning the entity’s financial reporting for hedging relationships with those risk management activities and simplifies the application of hedge accounting. The standard will make more financial and nonfinancial hedging strategies eligible for hedge accounting, amends the presentation and disclosure requirements for hedging activities and changes how entities assess hedge effectiveness. This guidance will be effective for annual reporting periods, including interim reporting within those periods, beginning after December 15, 2018, with early adoption permitted, and is required to be applied using a modified retrospective approach. The adoption of this standard will have no impact on the Company’s consolidated financial statements.

CLOUD COMPUTING

In August 2018, the FASB issued ASU 2018-15, Customer’s Accounting for Implementation Costs Incurred in a Cloud Computing Arrangement That Is a Service Contract. The standard allows entities who are customers in hosting arrangements that are service contracts to apply the existing internal-use software guidance to determine which implementation costs to capitalize as an asset related to the service contract and which costs to expense. The guidance specifies classification for capitalizing implementation costs and related amortization expense within the financial statements and requires additional disclosures. The guidance will be effective for annual reporting periods, including interim reporting within those periods, beginning after December 15, 2019. Early adoption is permitted and can be applied either retrospectively or prospectively. The Company is currently evaluating the transition methods and the impact of the adoption of this standard on the consolidated financial statements.

SUMMARY OF QUARTERLY RESULTS

 

For the quarter ended

millions of Canadian dollars

(except per share amounts)

  

Q4

2018

    

Q3

2018

    

Q2

2018

    

Q1

2018

    

Q4

2017

   

Q3

2017

    

Q2

2017

    

Q1   

2017   

 

Operating revenues

   $   1,799      $   1,495      $   1,423      $   1,807      $   1,473     $   1,427      $   1,469      $   1,857    

Net income (loss) attributable to common shareholders

     231        118        90        271        (228     81        101        312    

Adjusted net income attributable to common shareholders

     167        191        111        202        137       118        117        152    

Earnings per common share – basic

     0.98        0.51        0.38        1.17        (1.06     0.38        0.47        1.48    

Earnings per common share – diluted

     0.98        0.50        0.38        1.17        (1.06     0.38        0.47        1.47    

Adjusted earnings per common share – basic

     0.71        0.82        0.48        0.87        0.64       0.55        0.55        0.72    

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 the demand for energy and the cost of service. Quarterly results could also be affected by items outlined in the “Significant Items Affecting Earnings” section and mark-to-market adjustments.

 

EMERA 2018 ANNUAL REPORT

75


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 judgements 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 15, 2019    
LOGO     LOGO
Scott Balfour     Gregory Blunden
President and Chief Executive Officer     Chief Financial Officer

 

EMERA 2018 ANNUAL REPORT

76


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, 2018 and 2017, 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, 2018 and 2017, 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.

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 report 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.

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.

 

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77


INDEPENDENT AUDITOR’S REPORT

 

 

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.

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.

 

LOGO
Ernst & Young LLP
Halifax, Canada
February 15, 2019

 

EMERA 2018 ANNUAL REPORT

78


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 sheet of Emera Incorporated (the “Company“) as of December 31, 2018, the related consolidated statement of income, consolidated statement of comprehensive income, consolidated statement of changes in equity and consolidated statement of cash flows for the year 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, 2018, and the consolidated results of its operations and its consolidated cash flows for the year then ended, 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 audit. 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 audit in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether 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 audit 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 audit 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 include examining, on a test basis, evidence regarding the amounts and disclosures in the consolidated financial statements. Our audit 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 audit provides a reasonable basis for our opinion.

 

LOGO
Ernst & Young LLP
We have served as the Company’s auditor since 1998.
Halifax, Canada
February 15, 2019

 

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79


CONSOLIDATED FINANCIAL STATEMENTS

 

 

Emera Incorporated

CONSOLIDATED STATEMENTS OF INCOME

 

For the    Year ended December 31    
millions of Canadian dollars (except per share amounts)    2018      2017    

Operating revenues

     

Regulated electric

   $       4,852      $      4,721    

Regulated gas

     1,044        1,002    

Non-regulated

     628        503    

Total operating revenues (note 5)

     6,524        6,226    

Operating expenses

     

Regulated fuel for generation and purchased power

     1,677        1,638    

Regulated cost of natural gas

     388        379    

Non-regulated fuel for generation and purchased power

     225        209    

Non-regulated direct costs

     16        28    

Operating, maintenance and general

     1,564        1,372    

Provincial, state, and municipal taxes

     340        326    

Depreciation and amortization

     916        856    

Total operating expenses

     5,126        4,808    

Income from operations

     1,398        1,418    

Income from equity investments (note 6)

     154        124    

Other expenses, net

     23        25    

Interest expense, net

     713        698    

Income before provision for income taxes

     816        819    

Income tax expense (note 7)

     69        520    

Net income

     747        299    

Non-controlling interest in subsidiaries

     1        5    

Preferred stock dividends

     36        28    

Net income attributable to common shareholders

   $ 710      $ 266    

Weighted average shares of common stock outstanding (in millions) (note 9)

     

Basic

     233        213    

Diluted

     234        214    

Earnings per common share (note 9)

     

Basic

   $ 3.05      $ 1.25    

Diluted

   $ 3.04      $ 1.24    

Dividends per common share declared

   $ 2.2825      $ 2.1325    

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

 

EMERA 2018 ANNUAL REPORT

80


CONSOLIDATED FINANCIAL STATEMENTS

 

 

Emera Incorporated

CONSOLIDATED STATEMENTS OF

COMPREHENSIVE INCOME

 

For the    Year ended December 31  
millions of Canadian dollars    2018     2017  

 

Net income

   $       747     $       299  

Other comprehensive income (loss), net of tax

    

Foreign currency translation adjustment

     627       (464

Unrealized gains (losses) on net investment hedges (1) (2)

     (122     97  

Cash flow hedges

    

Net derivative gains (losses)

     2       10  

Less: reclassification adjustment for losses (gains) included in income (3)

     (6     8  

Net effects of cash flow hedges

     (4     18  

Unrealized gains on available-for-sale investment

    

Unrealized gain (loss) arising during the period

           5  

Less: reclassification adjustment for (gains) recognized in income

     (4     (1

Net unrealized holding gains (losses)

     (4     4  

Net change in unrecognized pension and post-retirement benefit obligation (4)

     9       40  

Other comprehensive income (loss) (5)

     506       (305

Comprehensive income (loss)

     1,253       (6

Comprehensive income (loss) attributable to non-controlling interest

     4        

Comprehensive Income (loss) of Emera Incorporated

   $ 1,249     $ (6

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

 

(1)

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.

(2)

Net of tax recovery of $9 million (2017 – $9 million tax expense) for the year ended December 31, 2018.

(3)

Net of tax recovery of nil (2017 – $1 million tax recovery) for the year ended December 31, 2018.

(4)

Net of tax recovery of $2 million (2017 – $4 million tax recovery) for the year ended December 31, 2018.

(5)

Net of tax recovery of $11 million (2017 – $4 million tax expense) for the year ended December 31, 2018.

 

EMERA 2018 ANNUAL REPORT

81


CONSOLIDATED FINANCIAL STATEMENTS

 

 

Emera Incorporated

CONSOLIDATED BALANCE SHEETS

 

As at    December 31      December 31    
millions of Canadian dollars    2018      2017    

Assets

     

Current assets

     

Cash and cash equivalents

   $ 316      $ 438    

Restricted cash (note 1)

     56        65    

Inventory (note 11)

     474        418    

Derivative instruments (notes 12 and 13)

     148        141    

Regulatory assets (note 14)

     165        138    

Receivables and other current assets (note 16)

     1,620        1,326    

Assets held for sale (note 17)

     53        –    
       2,832        2,526    

Property, plant and equipment, net of accumulated depreciation and amortization of $8,567 and $7,824, respectively (note 18)

     18,712        16,995    

Other assets

     

Deferred income taxes (note 7)

     175        138    

Derivative instruments (notes 12 and 13)

     19        112    

Regulatory assets (note 14)

     1,404        1,273    

Net investment in direct financing lease (note 20)

     475        481    

Investments subject to significant influence (note 6)

     1,316        1,215    

Goodwill (note 21)

     6,313        5,805    

Other long-term assets

     291        261    

Assets held for sale (note 17)

     777        –    
       10,770        9,285    

Total assets

   $ 32,314      $ 28,806    

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

 

EMERA 2018 ANNUAL REPORT

82


CONSOLIDATED FINANCIAL STATEMENTS

 

 

Emera Incorporated

CONSOLIDATED BALANCE SHEETS (continued)

 

As at    December 31      December 31  
millions of Canadian dollars    2018      2017  

Liabilities and Equity

     

Current liabilities

     

Short-term debt (note 22)

   $ 1,186      $ 1,241  

Current portion of long-term debt (note 24)

     1,119        741  

Accounts payable

     1,289        1,161  

Derivative instruments (notes 12 and 13)

     260        227  

Regulatory liabilities (note 14)

     251        226  

Other current liabilities (note 23)

     428        350  

Liabilities associated with assets held for sale (note 17)

     20        –    
       4,553        3,946  

Long-term liabilities

     

Long-term debt (note 24)

     14,292        13,140  

Deferred income taxes (note 7)

     1,320        1,023  

Derivative instruments (notes 12 and 13)

     105        83  

Regulatory liabilities (note 14)

     2,359        2,242  

Pension and post-retirement liabilities (note 19)

     641        559  

Other long-term liabilities (note 6 and 25)

     686        609  
       19,403        17,656  

Commitments and contingencies (note 26)

     

Equity

     

Common stock (note 8)

     5,816        5,601  

Cumulative preferred stock (note 27)

     1,004        709  

Contributed surplus

     84        76  

Accumulated other comprehensive income (loss) (note 10)

     338        (165

Retained earnings

     1,075        891  

Total Emera Incorporated equity

     8,317        7,112  

Non-controlling interest in subsidiaries (note 28)

     41        92  

Total equity

     8,358        7,204  

Total liabilities and equity

   $ 32,314      $ 28,806  

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

 

Approved on behalf of the Board of Directors   
LOGO    LOGO
M. Jacqueline Sheppard    Scott Balfour
Chair of the Board    President and Chief Executive Officer

 

EMERA 2018 ANNUAL REPORT

83


CONSOLIDATED FINANCIAL STATEMENTS

 

 

Emera Incorporated

CONSOLIDATED STATEMENTS OF CASH FLOWS

 

For the    Year ended December 31  
millions of Canadian dollars    2018     2017  

Operating activities

    

Net income

   $ 747     $ 299  

Adjustments to reconcile net income to net cash provided by operating activities:

    

Depreciation and amortization

     928       851  

Income from equity investments, net of dividends

     (75     (90

Allowance for equity funds used during construction

     (19     (9

Deferred income taxes, net (1)

     185       469  

Net change in pension and post-retirement liabilities

     11       (12

Regulated fuel adjustment mechanism

     (16     68  

Net change in fair value of derivative instruments

     55       (157

Net change in regulatory assets and liabilities (2)

     51       (237

Net change in capitalized transportation capacity

     (105     84  

Other operating activities, net

     44       31  

Changes in non-cash working capital (note 29)

     (116     (104

Net cash provided by operating activities

     1,690       1,193  

Investing activities

    

Additions to property, plant and equipment

     (2,162     (1,529

Net purchase of investments subject to significant influence, inclusive of acquisition costs

     (49     (213

Other investing activities

     21       (19

Net cash used in investing activities

     (2,190     (1,761

Financing activities

    

Change in short-term debt, net

     99       (31

Proceeds from short-term debt with maturities greater than 90 days

     129       383  

Repayment of short-term debt with maturities greater than 90 days

     (390      

Proceeds from long-term debt, net of issuance costs

     1,055       129  

Retirement of long-term debt

     (757     (453

Net borrowings (repayments) under committed credit facilities

     321       230  

Issuance of common stock, net of issuance costs

     10       682  

Issuance of preferred stock, net of issuance costs (note 27)

     291        

Dividends on common stock

     (346     (287

Dividends on preferred stock

     (36     (28

Other financing activities

     (32     (32

Net cash provided by financing activities

     344       593  

Effect of exchange rate changes on cash, cash equivalents, and restricted cash

     25       (13

Net increase (decrease) in cash, cash equivalents, and restricted cash

     (131     12  

Cash, cash equivalents, and restricted cash, beginning of year

     503       491  

Cash, cash equivalents and restricted cash, end of year

     372       503  

Cash, cash equivalents, and restricted cash consists of:

    

Cash

     273       216  

Short-term investments

     43       222  

Restricted cash

     56       65  

Cash, cash equivalents, and restricted cash

     372       503  

 

(1)

2017 includes $317 million for the revaluation of US non-regulated net deferred income tax assets as a result of US tax reform.

(2)

2017 includes the net impact of the change in deferred taxes as a result of US tax reform with an offset to a regulatory liability of $1.1 billion.

Supplementary Information to Consolidated Statements of Cash Flows (note 29)

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

 

EMERA 2018 ANNUAL REPORT

84


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, 2017

  

 

$

 

5,601

 

 

  

 

$

 

709

 

 

  

 

$

 

76

 

 

  

 

$

 

(165

 

 

 

$

 

891

 

 

 

 

$

 

92

 

 

 

 

$

 

7,204

 

 

Net income

                                746       1       747  

Other comprehensive income, net of tax recovery of $11 million

                          503             3       506  

Issuance of preferred stock, net of after-tax issuance costs

            295                                 295  

Dividends declared on preferred stock (note 27)

                                (36           (36

Dividends declared on common stock ($2.2825/share)

                                (528           (528

Common stock issued under purchase plan

     191                                        191  

Acquisition of non-controlling interest of ICD Utilities Limited (“ICDU”)

     22               6                    (53     (25

Other

     2               2              2       (2     4  

Balance, December 31, 2018

   $ 5,816      $       1,004      $ 84      $ 338     $ 1,075     $ 41     $ 8,358  

Balance, December 31, 2016

   $       4,738      $ 709      $       75      $       135     $       1,076     $       112     $       6,845  

Net income

                                294       5       299  

Other comprehensive income (loss), net of tax expense of $4 million

                          (300           (5     (305

Issuance of common stock, net of after-tax issuance costs

     686                                        686  

Dividends declared on preferred stock (note 27)

                                (28           (28

Dividends declared on common stock ($2.1325/share)

                                (451           (451

Common stock issued under purchase plan

     173                                        173  

Stock-based compensation

     3               1                          4  

Repurchase of preferred shares of GBPC (note 28)

                                      (14     (14

Other

     1                                  (6     (5

Balance, December 31, 2017

 

   $

 

5,601

 

 

 

   $

 

709

 

 

 

   $

 

76

 

 

 

   $

 

(165

 

 

  $

 

891

 

 

 

  $

 

92

 

 

 

  $

 

7,204

 

 

 

 

(1)

Accumulated Other Comprehensive Income (Loss) (“AOCI”) (“AOCL”).

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

 

EMERA 2018 ANNUAL REPORT

85


NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

 

Emera Incorporated

NOTES TO THE CONSOLIDATED

FINANCIAL STATEMENTS

As at December 31, 2018 and 2017

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, 2018, Emera’s primary rate-regulated subsidiaries and investments included the following:

 

   

Emera Florida and New Mexico represents TECO Energy, Inc. (“TECO Energy”), a holding company with regulated electric and gas utilities in Florida and New Mexico that include:

 

   

Tampa Electric Company (“TEC”), which holds the Tampa Electric Division (“Tampa Electric”), a vertically integrated regulated electric utility, serving approximately 764,000 customers in West Central Florida, and Peoples Gas System Division (“PGS”), a regulated gas distribution utility, serving approximately 392,000 customers across Florida;

 

   

New Mexico Gas Company, Inc. (“NMGC”), a regulated gas distribution utility, serving approximately 530,000 customers across New Mexico;

 

   

TECO Finance, Inc. (“TECO Finance”), a financing subsidiary of TECO Energy; and

 

   

SeaCoast Gas Transmission LLC (“SeaCoast”), a regulated intrastate natural gas transmission company offering services in Florida.

 

   

Nova Scotia Power Inc. (“NSPI”), a vertically integrated regulated electric utility and the primary electricity supplier in Nova Scotia, serving approximately 519,000 customers;

 

   

Emera Maine, a regulated electric transmission and distribution utility, serving approximately 159,000 customers in the state of Maine;

 

   

Emera Caribbean represents Emera (Caribbean) Incorporated (“ECI”), a holding company with regulated electric utilities that include:

 

   

The Barbados Light & Power Company Limited (“BLPC”), a vertically integrated utility and sole provider of electricity on the island of Barbados, serving approximately 130,000 customers;

 

   

Grand Bahama Power Company Limited (“GBPC”), a vertically integrated utility operating on Grand Bahama Island, serving approximately 19,000 customers. On January 15, 2018, Emera completed the acquisition of the minority shareholder common shares for total consideration of $35 million USD, increasing Emera’s interest in GBPC from 80.4 per cent to 100 per cent;

 

   

a 51.9 per cent interest in Dominica Electricity Services Ltd. (“Domlec”), a vertically integrated utility on the island of Dominica, serving approximately 26,000 customers; and

 

   

a 19.1 per cent indirect interest in St. Lucia Electricity Services Limited (“Lucelec”), a vertically integrated regulated electric utility on the island of St. Lucia.

 

   

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;

 

EMERA 2018 ANNUAL REPORT

86


NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

 

   

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 and forecasted to be generating first power in 2019 and full power in 2020. ENL’s two investments are:

 

   

a 100 per cent investment in NSP Maritime Link Inc. (“NSPML”), which developed the Maritime Link Project, a $1.56 billion transmission project, including two 170-kilometre subsea cables, connecting the island of Newfoundland and Nova Scotia. This project went in service on January 15, 2018; and

 

   

a 49.5 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 the energization phase of the project began in June 2018.

 

   

a 12.9 per cent interest in Maritimes & Northeast Pipeline (“M&NP”), a 1,400-kilometre pipeline, which transports natural gas from offshore Nova Scotia to markets in Atlantic Canada and the northeastern United States.

At December 31, 2018, Emera’s investments in other energy-related non-regulated companies included the following:

 

   

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;

 

   

Bridgeport Energy, Tiverton Power and Rumford Power (“New England Gas Generating Facilities” or “NEGG”), 1,115 MW of combined-cycle gas-fired electricity generating capacity in the northeastern United States. On November 26, 2018, Emera announced an agreement to sell its NEGG facilities. The transaction is expected to close in the first quarter of 2019. Refer to note 17 for additional information;

 

   

Bayside Power Limited Partnership (“Bayside Power”), a 290 MW gas-fired combined cycle power plant in Saint John, New Brunswick;

 

   

Brooklyn Power Corporation (“Brooklyn Energy”), a 30 MW biomass co-generation electricity facility in Brooklyn, Nova Scotia. Brooklyn Energy has a long-term purchase power agreement with NSPI; 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, a wholly owned financing subsidiary of Emera;

 

   

Emera US Holdings Inc., a wholly owned holding company for certain of Emera’s assets located in the United States;

 

   

Emera Utility Services Inc., a utility services contractor primarily operating in Atlantic Canada; and

 

   

other investments.

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. 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.

The Company performs ongoing analysis to assess whether it holds any 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. 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.

 

EMERA 2018 ANNUAL REPORT

87


NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

 

Intercompany balances and intercompany 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. Management evaluates the Company’s estimates on an ongoing basis based upon historical experience, current 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. 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 the costs of providing the regulated products or services and provide a reasonable rate of return on the equity invested or assets as applicable (refer to note 14 for additional details).

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, and the effective portion of the hedge, is recorded in Other Comprehensive Income (“OCI”). Any ineffectiveness is reflected in current period earnings.

REVENUE RECOGNITION

Regulated Electric Revenue

Electric 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 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 occur 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.

 

EMERA 2018 ANNUAL REPORT

88


NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

 

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 occur 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.

Direct Finance Lease

The Company records the net investment in a lease under the direct finance method for Emera Brunswick Pipeline, which 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 for a direct financing lease is recorded as unearned income at the inception of the lease. The 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” on the Consolidated Statements of Income.

Non-regulated Revenue

Marketing and trading margin is 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.

Other

Sales, value add, and other taxes, with the exception of gross receipts taxes discussed below, collected by the Company concurrent with revenue-producing activities are excluded from revenue.

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 2018 ANNUAL REPORT

89


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 executive, 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, land rights and naming rights with definite lives. 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 not classified as depreciable property above. 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 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 an annual assessment for impairment at the reporting unit level. Refer to note 21 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. 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 at the amount expected to be realized.

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, NMGC and Emera Maine on regulated assets are deferred and amortized over the estimated service lives of the related properties, as required by the regulatory practices.

 

EMERA 2018 ANNUAL REPORT

90


NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

 

Emera’s rate-regulated subsidiaries recognize regulatory assets or liabilities where the deferred income taxes are expected to be recovered from or returned to customers in future rates, unless specifically directed by a regulator to flow deferred income taxes through earnings. 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.

Emera classifies interest and penalties associated with unrecognized tax benefits as interest and operating expense, respectively. Refer to note 7 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 effective portion of 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. Any ineffective portion of the change in the fair value of the cash flow hedges is recognized in net income in the reporting period. 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 Tampa Electric, PGS, 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.

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, unless deferred as a result of regulatory accounting. 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 transactions is recognized as an asset in “Other” 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.

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”.

 

EMERA 2018 ANNUAL REPORT

91


NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

 

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. Total short-term investments of $43 million have an effective interest rate of 2.0 per cent at December 31, 2018 (2017 – $222 million with an effective interest rate of 1.4 per cent).

Included in restricted cash are funds required to be set aside for the BLPC Self-Insurance Fund (“SIF”) (note 31).

RECEIVABLES AND ALLOWANCE FOR DOUBTFUL ACCOUNTS

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 risk assessments are conducted on all new customers and deposits are requested on any high risk accounts. The Company also maintains provisions for potential credit losses, which are assessed on a regular basis.

Management estimates uncollectible accounts receivable after considering historical loss experience, customer deposits, current events and the characteristics of existing accounts. Provisions for 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.

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.

Emission credits inventory are measured using the first-in-first-out method. Emission credits inventory is recognized in inventory when purchased, or allocated by the respective government agency.

ASSET IMPAIRMENT

Long-Lived Assets

Emera assesses whether there has been an impairment of long-lived assets and intangibles when such indicators exist. The Company reviews all long-lived assets in the last quarter of each year to ensure that any gradual change over the year and the seasonality of the markets are considered when determining which assets require an impairment analysis. In the case of a triggering event, such as a significant market disruption or sale of a business, the values of related long-lived assets are reviewed outside of this annual analysis.

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.

Goodwill

Goodwill is not amortized, but is subject to an annual assessment for impairment at the reporting unit level. 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. Entities assessing goodwill for impairment have 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.

 

EMERA 2018 ANNUAL REPORT

92


NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

 

If an entity 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 an entity 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 entity’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 Emera’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.

Emera reviews recorded goodwill at least annually (during the fourth quarter) for each reporting unit to which goodwill has been allocated, with interim impairment tests performed when impairment indicators are present. No impairment provisions were required for either 2018 or 2017. Refer to note 21 for further detail.

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. 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.

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.

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.

As at December 31, 2018 and 2017, 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.

 

EMERA 2018 ANNUAL REPORT

93


NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

 

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; and a performance share unit (“PSU”) 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.

2. CHANGE IN ACCOUNTING POLICY

The new USGAAP accounting policies that are applicable to, and adopted by the Company in 2018, are described as follows:

RECLASSIFICATION OF CERTAIN TAX EFFECTS FROM ACCUMULATED OTHER COMPREHENSIVE INCOME

In February 2018, the Financial Accounting Standards Board (“FASB”) issued Accounting Standard Updates (“ASU”) No. 2018-02, Income Statement – Reporting Comprehensive Income (Topic 220): Reclassification of Certain Tax Effects from Accumulated Other Comprehensive Income. The standard allows reclassification from accumulated other comprehensive income to retained earnings for certain tax effects resulting from the US Tax Cuts and Jobs Act that would otherwise be stranded in accumulated other comprehensive income. This guidance is effective for annual reporting periods, including interim reporting within those periods, beginning after December 15, 2018, with early adoption permitted. The Company early adopted the standard in Q2 2018 and elected to not reclassify tax effects resulting from the US Tax Cuts and Jobs Act stranded in accumulated other comprehensive income to retained earnings as amounts were not material. Emera utilizes a portfolio approach to determine the timing and extent to which stranded income tax effects from items that were previously recorded in accumulated other comprehensive income are released.

REVENUE FROM CONTRACTS WITH CUSTOMERS

On January 1, 2018, the Company adopted ASU 2014-09, Revenue from Contracts with Customers and all the related amendments, which created a new, principle-based revenue recognition framework. The standard has been codified as Accounting Standards Codification (“ASC”) Topic 606. The core principle is that a company should recognize revenue when it transfers promised goods or services to customers in an amount that reflects the consideration to which the company expects to be entitled to. The guidance requires additional disclosures regarding the nature, amount, timing and uncertainty of revenue and related cash flows arising from contracts with customers. This guidance is effective for annual reporting periods, including interim reporting within those periods, beginning after December 15, 2017.

The Company adopted ASC 606 using the modified retrospective method. Results for reporting periods beginning after January 1, 2018 are presented under Topic 606, while prior period amounts are not adjusted and continue to be reported in accordance with historic accounting practices. The adoption of ASC 606 resulted in no adjustments to the Company’s opening retained earnings as of the adoption date. The impact of the adoption of the new standard was immaterial to the Company’s net income and is expected to be immaterial on an ongoing basis.

 

EMERA 2018 ANNUAL REPORT

94


NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

 

RECOGNITION AND MEASUREMENT OF FINANCIAL ASSETS AND FINANCIAL LIABILITIES

On January 1, 2018, the Company adopted ASU 2016-01, Financial Instruments – Recognition and Measurement of Financial Assets and Financial Liabilities and all of the related amendments. The standard provides guidance for the recognition, measurement, presentation and disclosure of financial assets and liabilities. This guidance is effective for annual reporting periods, including interim reporting within those periods, beginning after December 15, 2017.

The standard requires investments in equity securities, except those accounted for under the equity method of accounting or those that result in consolidation, to be measured at fair value. The Company has elected to measure equity securities that do not have a readily determinable fair value at cost minus impairment (if any), plus or minus observable price changes resulting from transactions for the identical or similar investments of the same issuer. The standard eliminates the available-for-sale classification for equity investments that recognized changes in the fair value as a component of other comprehensive income, resulting in all changes in fair value being recognized in net income. The impact as a result of the remeasurement of equity investments is expected to be immaterial to the Company’s net income on an ongoing basis. A cumulative-effect adjustment of $4 million was made which increased retained earnings in the Consolidated Balance Sheet as of January 1, 2018.

CLARIFYING THE DEFINITION OF A BUSINESS

In January 2017, the FASB issued ASU 2017-01, Clarifying the Definition of a Business. The standard provides guidance to assist entities with evaluating when a set of transferred assets and activities is a business. This guidance is effective for annual reporting periods, including interim reporting within those periods, beginning after December 15, 2017 and is required to be applied prospectively. The Company adopted ASU 2017-01 effective January 1, 2018. There was no impact on the consolidated financial statements as a result of the adoption of this standard.

IMPROVING THE PRESENTATION OF NET PERIODIC PENSION COST AND NET PERIODIC POSTRETIREMENT BENEFIT COST

In March 2017, the FASB issued ASU 2017-07, Compensation – Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost. The guidance requires the service cost component of defined benefit pension or other postretirement benefit plans to be reported in the same line items as other compensation costs. The other components of net benefit cost are required to be presented in the Consolidated Statements of Income outside of income from operations. Only the service cost component is eligible for capitalization as property, plant and equipment under this guidance. This guidance is effective for annual reporting periods, including interim reporting within those periods, beginning after December 15, 2017. The guidance is required to be applied retrospectively for presentation in the Consolidated Statements of Income and prospectively for the guidance around capitalization.

The Company adopted ASU 2017-07 effective January 1, 2018 and December 31, 2017 balances have been retrospectively restated in the Consolidated Statements of Income. The standard allows the Company to use the amounts disclosed in its pension and other postretirement benefit plan note for the prior comparative periods as the estimation basis for applying the retrospective presentation requirements. This change resulted in $27 million of costs, previously presented within “Operating, maintenance and general”, being reclassified to “Other income (expense), net” in the Consolidated Statements of Income for the year ended December 31, 2017.

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 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.

LEASES

In February 2016, the FASB issued ASU 2016-02, Leases. The standard, codified as ASC Topic 842, increases transparency and comparability among organizations by recognizing lease assets and liabilities on the balance sheet for leases with terms of more than 12 months. Under the previous guidance, operating leases are not recorded as assets and liabilities on the balance sheet. The effect of leases on the Consolidated Statements of Income and the Consolidated Statements of Cash Flows is largely

 

EMERA 2018 ANNUAL REPORT

95


NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

 

unchanged. The guidance will require additional disclosures regarding key information about leasing arrangements. This guidance is effective for annual reporting periods, including interim reporting within those periods, beginning after December 15, 2018. Early adoption is permitted and is required to be applied using a modified retrospective approach. The Company will not early adopt the standard.

In January 2018, the FASB issued an amendment to ASC Topic 842 that permits companies to elect to not evaluate existing land easements under the new standard if the land easements were not previously accounted for under existing lease guidance. The Company will make this election. In July 2018, the FASB issued an amendment to ASC Topic 842 that permits companies to elect not to restate their comparative periods in the period of adoption when transitioning to the standard. The Company will make this election. Additionally, the Company will elect the options that allow the Company to not reassess whether any expired or existing contracts contain leases, carry forward existing lease classification, use hindsight to determine the lease term for existing leases and not separate lease components from non-lease components for all lessee and lessor arrangements.

Over the past several years, the Company developed and executed a project plan which included holding training sessions with key stakeholders throughout the organization, gathering detailed information on existing lease arrangements, evaluating implementation alternatives and calculating the lease asset and liability balances associated with individual contractual arrangements. The Company has implemented additional processes and controls to facilitate the identification, tracking and reporting of potential leases based on the requirements of the standard. Updates to systems are not required as a result of implementation of this standard. The adoption of this standard will affect the Company’s financial position by increasing assets and liabilities related to operating leases by approximately $70 million, with no impact to the Company’s Consolidated Statements of Income. There will be no significant changes to the Company’s accounting for lessor arrangements as a result of the adoption of the standard. The Company is in the process of assessing the disclosure requirements and continues to monitor FASB amendments to ASC Topic 842.

MEASUREMENT OF CREDIT LOSSES ON FINANCIAL INSTRUMENTS

In June 2016, the FASB issued ASU 2016-13, Measurement of Credit Losses on Financial Instruments. 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, including 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.

This guidance will be effective for annual reporting periods, including interim reporting within those periods, beginning after December 15, 2019. Early adoption is permitted for annual reporting periods, including interim periods after December 15, 2018 and will be applied using a modified retrospective approach. The Company is currently evaluating the impact of adoption of this standard on its consolidated financial statements.

TARGETED IMPROVEMENTS TO ACCOUNTING FOR HEDGING ACTIVITIES

In August 2017, the FASB issued ASU 2017-12, Targeted Improvements to Accounting for Hedging Activities, which amends the hedge accounting recognition and presentation requirements in ASC Topic 815. This standard improves the transparency and understandability of information about an entity’s risk management activities by better aligning the entity’s financial reporting for hedging relationships with those risk management activities and simplifies the application of hedge accounting. The standard will make more financial and nonfinancial hedging strategies eligible for hedge accounting, amends the presentation and disclosure requirements for hedging activities and changes how entities assess hedge effectiveness. This guidance will be effective for annual reporting periods, including interim reporting within those periods, beginning after December 15, 2018, with early adoption permitted, and is required to be applied using a modified retrospective approach. The adoption of this standard will have no impact on the Company’s consolidated financial statements.

 

EMERA 2018 ANNUAL REPORT

96


NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

 

CLOUD COMPUTING

In August 2018, the FASB issued ASU 2018-15, Customer’s Accounting for Implementation Costs Incurred in a Cloud Computing Arrangement That Is a Service Contract. The standard allows entities who are customers in hosting arrangements that are service contracts to apply the existing internal-use software guidance to determine which implementation costs to capitalize as an asset related to the service contract and which costs to expense. The guidance specifies classification for capitalizing implementation costs and related amortization expense within the financial statements and requires additional disclosures. The guidance will be effective for annual reporting periods, including interim reporting within those periods, beginning after December 15, 2019. Early adoption is permitted and can be applied either retrospectively or prospectively. The Company is currently evaluating the transition methods and the impact of the adoption of this standard on the consolidated financial statements.

4. SEGMENT INFORMATION

Emera manages its reportable segments separately due in part to their different geographical, operating and regulatory 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 six reportable segments are Emera Florida and New Mexico, NSPI, Emera Maine, Emera Caribbean, Emera Energy and Corporate and Other (includes Emera Utility Services, ENL, Emera Brunswick Pipeline, Corporate, other strategic investments and certain holding companies). The Company is reviewing its internal reporting to the chief operating decision maker and considering changes to its reportable segments for 2019.

 

millions of Canadian dollars           

Emera

Florida

and

New Mexico

     NSPI      Emera
Maine
     Emera
Caribbean
     Emera
Energy
     Corporate
and
Other
  

Inter-
segment

Eliminations

     Total  

For the year ended December 31, 2018

 

                    

Operating revenues from
external customers (1)

   $    3,675        $    1,437      $       278      $     467      $     600        $    68        $         –      $    6,525  

Inter-segment revenues (1)

            3                      14      36      (54      (1
                 

Total operating revenues

     3,675        1,440        278        467        614      104      (54      6,524  

AFUDC - debt and equity

     21        6        3                                30  

Regulated fuel and fixed cost deferral adjustments

            (46                                     (46

Depreciation and amortization

     534        219        64        50        46      3             916  

Interest expense (2)

     238        142        22        27        5      290             724  

Internally allocated interest (3)

                                 (24    24              

Income from equity investments

                   3        3        38      110             154  

Income tax expense (recovery)

     101        8        11        (2      66      (115)             69  

Net income attributable to common shareholders

     428        131        44        41        165      (99)             710  

Capital expenditures

     1,548        345        100        87        33      38             2,151  

As at December 31, 2018

                       

Total assets

     20,051        5,143        1,721        1,373        1,785      2,275      (34      32,314  

Investments subject to significant influence (4)

                   35        42             1,239             1,316  

Goodwill

     6,053               156        104                         6,313  

 

(1)

All significant intercompany balances and intercompany 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. Intercompany transactions which 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)

Interest expense is net of interest revenue. Corporate and Other Interest expense has also been reduced by amortization of $12 million related to the unregulated long-term debt fair market value adjustment recognized on the acquisition of TECO Energy.

(3)

Segment net income is reported on a basis that includes internally allocated financing costs.

(4)

Emera Energy’s segment includes an investment in Bear Swamp. At December 31, 2018 this investment is in a credit position of $172 million and is recorded in “Other long-term liabilities” on the Consolidated Balance Sheets.

 

EMERA 2018 ANNUAL REPORT

97


NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

 

millions of Canadian dollars   

Emera
Florida

and
New Mexico

     NSPI      Emera
Maine
     Emera
Caribbean
     Emera
Energy
    

Corporate
and

Other

     Inter-
segment
Eliminations
     Total  

For the year ended December 31, 2017

 

                    

Operating revenues from external customers (1)

   $   3,623      $     1,335      $       297      $      434      $       451      $       86      $      $     6,226  

Inter-segment revenues (1)

            3                      14        41        (58       
                 

Total operating revenues

     3,623        1,338        297        434        465        127        (58      6,226  

AFUDC – debt and equity

     5        8        3                                    16  

Regulated fuel and fixed cost deferral adjustments

            59                                           59  

Depreciation and amortization

     500        207        47        51        48        3               856  

Interest expense (2)

     248        134        20        25        2        276               705  

Internally allocated interest (3)

                                 (24      24                

Income from equity investments

                   1        3        24        96               124  

Income tax expense (recovery)

     529               27               18        (54             520  

Net income attributable to common shareholders

     99        129        46        31        93        (132             266  

Capital expenditures

     910        385        82        72        47        26               1,522  

As at December 31, 2017

                       

Total assets

     17,216        4,979        1,540        1,251        1,575        2,331        (86      28,806  

Investments subject to significant influence (4)

                   13        39               1,163               1,215  

Goodwill

     5,566               143        96                             5,805  

 

(1)

All significant intercompany balances and intercompany 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. Intercompany transactions which 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)

Interest expense is net of interest revenue. Corporate and Other Interest expense has also been reduced by amortization of $24 million related to the unregulated long-term debt fair market value adjustment recognized on the acquisition of TECO Energy.

(3)

Segment net income is reported on a basis that includes internally allocated financing costs.

(4)

Emera Energy’s segment includes an investment in Bear Swamp. At December 31, 2017 this investment is in a credit position of $188 million and is recorded in “Other long-term liabilities” on the Consolidated Balance Sheets.

GEOGRAPHICAL INFORMATION

Revenues (1):

 

For the    Year ended December 31    
     

millions of Canadian dollars

 

  

2018

 

    

2017  

 

 

Canada

   $     1,520      $     1,464    

United States

     4,537            4,328    

Barbados

     319        280    

The Bahamas

     121        119    

Dominica

     27        35    
     
     $     6,524      $     6,226    

 

(1)

Revenues are based on country of origin of the product or service sold.    

 

EMERA 2018 ANNUAL REPORT

98


NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

 

Property Plant and Equipment:

 

As at    December 31      December 31    
millions of Canadian dollars                2018      2017    

Canada

   $ 4,128        $          3,995    

United States

     13,739        12,257    

Barbados

     446        408    

The Bahamas

     315        276    

Dominica

     84        59    
     $     18,712        $        16,995    

5. REVENUE

The following disaggregates the Company’s revenue by major source:

 

millions of Canadian dollars     


Emera
Florida

and
New Mexico

 
 

 
 

     NSPI       
Emera
Maine
 
 
    
Emera
Caribbean
 
 
    
Emera
Energy
 
 
    

Corporate
and

Other

 
 

 

    

Inter-
segment
Eliminations
 
 
 
    Total    

For the year ended December 31, 2018

                      

Regulated

                      

Electric Revenue

                      

Residential

   $ 1,384      $ 731      $ 107      $ 154      $      $      $     $ 2,376    

Commercial

     755        405        80        270                            1,510    

Industrial

     209        233        16        30                            488    

Other electric and regulatory

                      

deferrals

     312        43        9        7                            371    

Other (1)

     10        28        66        6                      (3     107    

Regulated electric revenue

     2,670        1,440        278        467                      (3     4,852    

Gas Revenue

                      

Residential

     492                                                 492    

Commercial

     291                                                 291    

Industrial

     49                                                 49    

Finance income (2) (3)

                                        57              57    

Other

     155                                                 155    

Regulated gas revenue

     987                                    57              1,044    

Non-Regulated

                      

Marketing and trading margin (4)

                                 115                     115    

Energy sales (4)

                                 309               (16     293    

Capacity

                                 136                     136    

Other

     18                                    47        (35     30    

Mark-to-market (3)

                                 54                     54    

Non-regulated revenue

     18                             614        47        (51     628    

Total operating revenues

   $ 3,675      $     1,440      $     278      $ 467      $ 614      $ 104      $ (54   $     6,524    

 

(1)

Other includes an immaterial amount of 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 2018 ANNUAL REPORT

99


NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

 

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, 2018, the aggregate amount of the transaction price allocated to remaining performance obligations was $370 million. As allowed by the practical expedient in ASC 606, 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 2033.

6. INVESTMENTS SUBJECT TO SIGNIFICANT INFLUENCE AND EQUITY INCOME

Investments subject to significant influence consisted of the following:

 

millions of Canadian dollars   

Carrying Value

As at December 31

    

Equity Income

For the year ended

December 31

     Percentage  
of  
Ownership  
 
     

2018

 

    

2017

 

    

2018

 

    

2017

 

    

2018  

 

 

NSPML

   $ 545      $ 510      $ 45      $ 36        100.0    

LIL (1)

     534        492        42        37        49.5    

M&NP (2)

     155        156        22        23        12.9    

Lucelec (2)

     42        39        3        3        19.1    

Bear Swamp (3)

                   38        23        50.0    

Other Investments

     40        18        4        2           
     $       1,316      $       1,215      $       154      $       124           

 

(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 a result of a $179 million distribution received in Q4 2015. Bear Swamp’s credit investment balance of $172 million (2017 – $188 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.

Emera accounts for its variable interest investment in NSPML as an equity investment (note 31). NSPML’s consolidated summarized balance sheets are illustrated as follows:

 

 

As at    December 31      December 31    
millions of Canadian dollars    2018      2017    

Balance Sheets

     

Current assets

   $ 86      $ 225    

Property, plant and equipment

     1,690        1,720    

Non-current assets

     140        74    

Total assets

   $ 1,916      $ 2,019    

Current liabilities

   $ 21      $ 180    

Long-term debt

     1,288        1,287    

Non-current liabilities

     62        42    

Equity

     545        510    

Total liabilities and equity

   $       1,916      $       2,019    

 

EMERA 2018 ANNUAL REPORT

100


NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

 

7. INCOME TAXES

The income tax provision, for the years ended December 31, differs from that computed using the enacted combined Canadian federal and Nova Scotia and New Brunswick provincial statutory income tax rate for the following reasons:

 

millions of Canadian dollars    2018        2017    

Income before provision for income taxes

   $           816        $         819  

Statutory income tax rate

     31%          31%  

Income taxes, at statutory income tax rate

     253          254  

Deferred income taxes on regulated income recorded as regulatory assets and regulatory liabilities

     (59        (54

Foreign tax rate variance

     (55        36  

Amortization of deferred income tax regulatory liabilities

     (37         

Florida state tax apportionment adjustment

     (23         

Tax effect of equity earnings

     (15        (12

Financing deductions

     (4        (17

Revaluation of US non-regulated deferred income taxes due to tax reform

              317  

Other

     9          (4

Income tax expense (recovery)

   $ 69        $ 520  

Effective income tax rate

     8%          63%  

On December 22, 2017, the US Tax Cuts and Jobs Act of 2017 (“the Act”) was signed into law enacting a broad range of legislative changes including reduction of the US federal corporate income tax rate from 35 per cent to 21 per cent effective January 1, 2018, limitations on the deductibility of interest and 100 per cent expensing of qualified property. The Act provides an exemption to regulated electric and gas utilities from the limitations on the deductibility of interest and the 100 per cent expensing of qualified property.

At December 31, 2017, the Company was required to revalue its US deferred income tax assets and liabilities based on the new tax rate at the date of enactment. The Company recognized a $317 million income tax expense as a result of the revaluation of its US non-regulated net deferred income tax assets. The Company also reduced its US regulated net deferred income tax liabilities by $1.1 billion and recorded an equivalent regulatory liability since the benefit of lower US taxes is expected to be returned to customers over time as required by the Act or by order of the applicable regulator. The December 31, 2017 balances of deferred income tax assets and liabilities that were revalued were $1.3 billion and $1.8 billion, respectively.

No further adjustments were recognized in 2018 and the Company has completed its accounting for the revaluation of its US deferred income tax assets and liabilities resulting from the effects of the Act. The measurement period allowed by SEC Staff Accounting Bulletin 118, Income Tax Accounting Implications of the Tax Cuts and Jobs Act is now closed.

In Q4 2018, the Company reclassified $149 million of AMT credit carryforwards from deferred income tax assets to receivables and other current assets as it expects to receive the refund in 2019.

On November 26, 2018, the Internal Revenue Service (“IRS”) issued proposed regulations on the interest deductibility limitation rules legislated under the Act. The Company believes its US based financing interest will be deductible under the Act.

 

EMERA 2018 ANNUAL REPORT

101


NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

 

The following 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    2018     2017  

Current income taxes

    

Canada

   $             3     $         24  

United States

     (121     24  

Other

     2       3  

Deferred income taxes

    

Canada

     11       3  

United States

     211       384  

Other

     (3     (1

Operating loss carryforwards

    

Canada

     (33     (40

United States

           (194

Other

     (1      

Revaluation of US non-regulated deferred income taxes

    

United States

           317  

Income tax expense (recovery)

   $ 69     $ 520  
The following 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    2018     2017  

Canada

   $             127     $         88  

United States

     646       693  

Other

     43       38  

Income before provision for income taxes

   $ 816     $ 819  
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    2018     2017  

Deferred income tax assets:

    

Tax loss carryforwards

   $         917     $         853  

Tax credit carryforwards

     269       314  

Regulatory liabilities – cost of removal

     206       208  

Pension and post-retirement liabilities

     126       112  

Derivative instruments

     90       107  

Other

     441       394  

Total deferred income tax assets before valuation allowance

     2,049       1,988  

Valuation allowance

     (163     (105

Total deferred income tax assets after valuation allowance

   $ 1,886     $ 1,883  

Deferred income tax (liabilities):

    

Property, plant and equipment

   $ (2,591   $ (2,321

Derivative instruments

     (124     (155

Other

     (316     (292

Total deferred income tax liabilities

   $ (3,031   $ (2,768

Consolidated Balance Sheets presentation:

    

Long-term deferred income tax assets

   $ 175     $ 138  

Long-term deferred income tax liabilities

     (1,320     (1,023

Net deferred income tax liabilities

   $ (1,145   $ (885

 

EMERA 2018 ANNUAL REPORT

102


NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

 

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 $163 million has been recorded as at December 31, 2018 (2017 – $105 million) related to the loss carryforwards and investments.

Emera’s net operating loss (“NOL”), capital loss and tax credit carryforwards and their expiration periods as at December 31, 2018 consisted of the following:

 

millions of Canadian dollars    Gross Tax
Carryforwards
     Unrecognized
Amounts
    Net Tax
Carryforwards
   

Expiration   

Period   

Canada

         

NOL

   $ 817      $ (405   $ 412     2027-2038  

Capital loss

     86        (77     9     Indefinite  

United States

         

Federal NOL

   $ 2,848      $     $ 2,848     2024-2037  

State NOL

     1,314        (47     1,267     2024-2038  

Capital loss

     6        (6         2019  

Tax credit

     268              268     2019-Indefinite  

Other

         

NOL

   $ 34      $ (34   $     2019-2025  

The following table provides details of the change in unrecognized tax benefits for the years ended December 31 as follows:    

 

millions of Canadian dollars    2018     2017     

Balance, January 1

   $         19     $         18    

Increases due to tax positions related to a prior year

     8       –    

Decreases due to tax positions related to a prior year

     (1     –    

Increases due to tax positions related to current year

     –         1    

Balance, December 31

   $ 26     $ 19    

The total amount of unrecognized tax benefits as at December 31, 2018 was $26 million (2017 – $19 million), which would affect the effective tax rate if recognized. The total amount of accrued interest with respect to unrecognized tax benefits was $4 million (2017 – $1 million) with $3 million of interest expense recognized in the Consolidated Statement of Income (2017 – nil). No penalties have been accrued. The balance of unrecognized tax benefits could change in the next twelve months as a result of resolving Canada Revenue Agency (“CRA”) and IRS audits. A reasonable estimate of any change cannot be made at this time.

The Company intends to indefinitely reinvest earnings from certain foreign operations. Accordingly, US and non-US income and withholding taxes for which deferred taxes might otherwise be required have not been provided for on a cumulative amount of temporary differences related to investments in foreign subsidiaries of approximately $1.4 billion as at December 31, 2018 (2017 – $822 million). It is impractical to estimate the amount of income and withholding tax that might be payable if a reversal of temporary differences occurred.

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, 2018, the Company’s tax years still open to examination by taxing authorities include 2005 and subsequent years.

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.

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 receive similar notices of reassessment for years not currently in dispute, further payments will be required; however, the ultimate permissibility of these deductions would be similarly not in dispute.

 

EMERA 2018 ANNUAL REPORT

103


NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

 

NSPI and its advisors believe NSPI has reported its tax position appropriately and NSPI is disputing the reassessments through the CRA Appeal process. NSPI continues to assess its options to resolving the dispute; however, the outcome of the Appeal process is not determinable at this time.

8. COMMON STOCK    

Authorized: Unlimited number of non-par value common shares.    

 

              2018             2017     
Issued and outstanding:    millions of
shares
    

 

millions of
Canadian
dollars

    millions of
shares
    

 

millions of   

Canadian   

dollars   

 

Balance, December 31, 2017

     228.77      $ 5,601       210.02      $ 4,738    

Conversion of Convertible Debentures

     0.01              0.15        6    

Issuance of common stock (1)

     0.45        22       14.61        680    

Issued under Purchase Plans at market rate

     4.87        200       3.89        182    

Discount on shares purchased under Dividend Reinvestment Plan

            (9            (9)   

Options exercised under senior management share option plan

     0.02        1       0.10        3    

Employee Share Purchase Plan

            1              1    

Balance, December 31, 2018

     234.12      $ 5,816       228.77      $ 5,601    

 

(1)

In Q1 2018, Emera issued 0.45 million common shares to facilitate the creation and issuance of 1.8 million depository receipts in connection with the ICDU share acquisition. The depository receipts are listed on the Bahamas International Securities Exchange.

As at December 31, 2018, the following common shares were reserved for issuance: 6.5 million (2017 – 6.5 million) under the senior management stock option plan, 1.0 million (2017 – 1.3 million) under the employee common share purchase plan and 12.6 million (2017 – 4.2 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, 2018, Emera is in compliance with this requirement.

9. 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)

 

   2018      2017  

Numerator

     

Net income attributable to common shareholders

   $ 709.6      $ 266.1  

Diluted numerator

     709.6        266.1  

Denominator

     

Weighted average shares of common stock outstanding

     231.7        212.3  

Weighted average deferred share units outstanding

     1.3        1.1  

Weighted average shares of common stock outstanding – basic

     233.0        213.4  

Stock-based compensation

     0.4        0.6  

Convertible Debentures

     0.1        0.1  

Weighted average shares of common stock outstanding – diluted

     233.5        214.1  

Earnings per common share

     

Basic

   $ 3.05      $ 1.25  

Diluted

   $ 3.04      $ 1.24  

 

EMERA 2018 ANNUAL REPORT

104


NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

 

10. 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  

Balance, January 1, 2018

   $ 30     $ 48     $ (3   $ 3     $ (243   $ (165

Other comprehensive income (loss) before reclassifications

     624       (122     2           –               –       504  

Amounts reclassified from accumulated other comprehensive income loss

             –               –       (6     (4     9       (1

Net current period other comprehensive income (loss)

     624       (122     (4     (4     9       503  

Balance, December 31, 2018

   $ 654     $ (74   $ (7   $ (1   $ (234   $ 338  
                                                  

For the year ended December 31, 2017

                                                

Balance, January 1, 2017 (1)

   $ 489     $ (49   $ (21   $ (1   $ (283   $ 135  

Other comprehensive income (loss) before reclassifications

     (459     97       10       5               –       (347

Amounts reclassified from accumulated other comprehensive income loss (gain) (2)

             –               –       8       (1     40       47  

Net current period other comprehensive income (loss)

     (459     97       18       4       40       (300

Balance, December 31, 2017

   $ 30     $ 48     $ (3   $ 3     $ (243   $ (165

 

(1)

The January 1, 2017 balance of AOCI and Regulatory Assets includes a prior period reclassification of $44 million in unrecognized pension and post-retirement benefit costs and $18 million in deferred taxes ($26 million, net of tax) to be consistent with current year presentation.

(2)

Certain net changes in unrecognized pension and post-retirement benefit costs for Emera Maine of $4 million were previously presented as a change in AOCI and are now presented as a change in Regulatory Assets for the year ended December 31, 2017 to be consistent with current year presentation.

 

EMERA 2018 ANNUAL REPORT

105


NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

 

The reclassifications out of accumulated other comprehensive income (loss) are as follows:

 

For the

          Year ended December 31  

millions of Canadian dollars

          2018       2017  
    

Affected line item in the Consolidated Financial Statements

                

Losses (gain) on derivatives recognized as cash flow hedges

    

Power and gas swaps

   Non-regulated fuel for generation and purchased power    $ (1   $ (3)   

Foreign exchange forwards

   Operating revenue – regulated      (5     10    

Total before tax

          (6     7    
     Income tax recovery (expense)            1    

Total net of tax

        $ (6   $ 8    

Net change in available-for-sale investments

                
     Other income (expenses), net    $     $ (1)   
     Retained earnings (1)      (4     –    

Total net of tax

        $ (4   $ (1)   

Net change in unrecognized pension and post-retirement benefit costs

    

Actuarial losses (gains)

   Operating, maintenance and general (“OM&G”)    $ 25     $ 33    

Past service costs (gains)

   OM&G      (1     (8)   

Amounts reclassified into obligations

   Pension and post-retirement benefits      (17     11    

Total before tax

          7       36    
     Income tax recovery (expense)      2       4    

Total net of tax

        $         9     $ 40    

Total reclassifications out of AOCI, net of tax, for the period

   $ (1   $         47    

 

(1)

Related to the adoption of ASU 2016-01, Financial Instruments – Recognition and Measurement of Financial Assets and Financial Liabilities. Refer to note 2 for additional detail.

11. INVENTORY

Inventory consisted of the following:

 

As at

millions of Canadian dollars

   December 31
2018
      

December 31  

2017  

 

Fuel

   $ 213        $ 180    

Materials

     241          216    

Emission credits (1)

     20          22    
     $         474        $         418    

 

(1)

The NEGG facilities are subject to the Acid Rain Program for sulphur dioxide emissions and the Regional Greenhouse Gas Initiative for carbon dioxide emissions. The emission credits inventory balance represents the credits purchased to offset the other current liabilities and other long-term liabilities associated with these programs.

 

EMERA 2018 ANNUAL REPORT

106


NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

 

12. DERIVATIVE INSTRUMENTS

Derivative assets and liabilities relating to the foregoing categories consisted of the following:

 

                                                                                   
      Derivative Assets     Derivative Liabilities  

As at

millions of Canadian dollars

   December 31
2018
    December 31
2017
    December 31
2018
    December 31
2017
 

Cash flow hedges

        

Power swaps

   $         –     $         5     $         –     $         2  

Foreign exchange forwards

           2       5       5  
             7       5       7  

Regulatory deferral

        

Commodity swaps and forwards

        

Coal purchases

     71       137       1       10  

Power purchases

     2       5       1       3  

Natural gas purchases and sales

     2       6       4       7  

Heavy fuel oil purchases

     1       15       1       4  

Foreign exchange forwards

     29       32             4  
       105       195       7       28  

HFT derivatives

        

Power swaps and physical contracts

     62       125       76       162  

Natural gas swaps, futures, forwards, physical contracts

     125       105       403       294  
       187       230       479       456  

Other derivatives

        

Interest rate swap

     1       2             –   
       1       2             –   

Total gross current derivatives

     293       434       491       491  

Impact of master netting agreements with intent to settle net or simultaneously

     (126     (181     (126     (181
       167       253       365       310  

Current

     148       141       260       227  

Long-term

     19       112       105       83  

Total derivatives

   $ 167     $ 253     $ 365     $ 310  

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

millions of Canadian dollars

   December 31
2018
     December 31
2017
     December 31
2018
     December 31
2017
 

Regulatory deferral

   $ 1      $ 14      $ 1      $ 14  

HFT derivatives

     125        167        125        167  

Total impact of master netting agreements with intent to settle net or simultaneously

   $         126      $ 181      $         126      $         181  

CASH FLOW HEDGES

The Company enters into various derivatives designated as cash flow hedges. Emera enters into power swaps to limit Bear Swamp’s exposure to purchased power prices. The Company also enters into foreign exchange forwards to hedge the currency risk for revenue streams denominated in foreign currency for Brunswick Pipeline.

 

EMERA 2018 ANNUAL REPORT

107


NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

 

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                   

 

2018

 

                    

 

2017

 

 
     

Power
swaps

 

    

Interest
rate
swaps

 

    

Foreign
exchange
forwards

 

    

Power
swaps

 

    

Interest
rate
swaps

 

    

Foreign
exchange
forwards

 

 

 

Realized gain (loss) in non-regulated fuel for generation and purchased power

   $ 1      $      $      $ 3      $      $         –  

Realized gain (loss) in operating revenue - regulated

                   5                      (10

Total gains (losses) in Net income

   $         1      $         –      $         5      $         3      $         –      $ (10

As at

 

                                  

Year ended
December 31

 

 
millions of Canadian dollars                    2018                      2017  
      Power
swaps
     Interest
rate
swaps
     Foreign
exchange
forwards
     Power
swaps
     Interest
rate
swaps
     Foreign
exchange
forwards
 

Total unrealized gain (loss) in AOCI - effective portion, net of tax

  

 

$

 

 

(1

 

 

 

  

 

$

 

 

 

 

 

 

 

 

 

  

 

$

 

 

(6

 

 

 

  

 

$

 

 

 

 

 

 

  

 

$

 

 

 

 

 

 

  

 

$

 

 

(3

 

 

 

The Company expects $4 million of unrealized losses currently in AOCI to be reclassified into net income within the next twelve months, as the underlying hedged transactions settle.

As at December 31, 2018, the Company had the following notional volumes of outstanding derivatives designated as cash flow hedges that are expected to settle as outlined below:

 

millions   

2019

 

    

2020

 

            

2021

 

 

Foreign exchange forwards (USD) sales

   $

 

        30

 

 

 

   $

 

        30

 

 

 

   $

 

 

 

 

 

    

 

 

 

 

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

 

                 

 

2018

 

                 

 

2017

 

 
     

Commodity
swaps and
forwards

 

   

Physical
natural gas
purchases and
sales

 

    

Foreign
exchange
forwards

   

Physical
natural gas
purchases and
sales

 

   

Physical

natural gas

purchases and

sales

 

   

Foreign
exchange
forwards

 

Unrealized gain (loss) in regulatory assets

  

 

$

 

(34

 

 

 

$

 

 

 

  

 

$

 

4

 

 

 

 

$

 

(33

 

 

 

$

 

(1

 

 

 

$

 

(4

 

Unrealized gain (loss) in regulatory liabilities

     29              24       83       1       (30

Realized (gain) loss in regulatory liabilities

     (8                  (2            

Realized (gain) loss in inventory (1)

     (55            (18     (17           (30

Realized (gain) loss in regulated fuel for generation and purchased power (2)

     (2         

 

(9

    (3           (14

Total change derivative instruments

  

 

$

 

 

(70

 

 

 

 

 

$

 

 

 

 

 

 

  

 

$

 

 

1

 

 

 

 

 

 

$

 

 

28

 

 

 

 

 

 

$

 

 

 

 

 

 

 

 

$

 

 

(78

 

 

 

(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; hedging relationships that have been terminated or the hedged transaction is no longer probable.

 

EMERA 2018 ANNUAL REPORT

108


NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

 

COMMODITY SWAPS AND FORWARDS

As at December 31, 2018, 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

 

  

2019

 

    

2020–2023

 

 
     

 

Purchases

 

    

 

Purchases

 

 

Coal (metric tonnes)

     1        1  

Natural Gas (Mmbtu)

     16         

Heavy fuel oil (bbls)

 

    

 

 

 

 

    

 

1

 

 

 

FOREIGN EXCHANGE SWAPS AND FORWARDS

As at December 31, 2018, the Company had the following notional volumes of foreign exchange swaps and forward contracts related to commodity contracts that are expected to settle as outlined below:

 

     

2019

 

    

2020

 

 

Foreign exchange contracts (millions of US dollars)

   $ 121      $ 111  

Weighted average rate

         1.1621            1.3027  

% of USD requirements

 

    

 

66%

 

 

 

    

 

48%

 

 

 

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

 

  

 

2018

 

   

 

2017

 

 

Power swaps and physical contracts in non-regulated operating revenues

   $ (12   $ 7  

Natural gas swaps, forwards, futures and physical contracts in non-regulated operating revenues

     205       401  

Natural gas swaps, forwards, futures and physical contracts in non-regulated fuel for generation and purchased power

           10  

Power swaps, forwards, futures and physical contracts in non-regulated fuel for generation and purchased power

    

 

2

 

 

 

   

 

2

 

 

 

    

 

$

 

 

    195

 

 

 

 

 

 

$

 

 

    420

 

 

 

 

As at December 31, 2018, the Company had the following notional volumes of outstanding HFT derivatives that are expected to settle as outlined below:

 

millions

 

  

2019

 

    

2020

 

    

2021

 

    

2022

 

    

2023

 

 

Natural gas purchases (Mmbtu)

     308        108        71        50        41  

Natural gas sales (Mmbtu)

     247        42        9        2         

Power purchases (MWh)

     6                              

Power sales (MWh)

 

    

 

5

 

 

 

    

 

 

 

 

    

 

 

 

 

    

 

 

 

 

    

 

 

 

 

 

EMERA 2018 ANNUAL REPORT

109


NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

 

OTHER DERIVATIVES

For the  

Year ended December 31

 

 

millions of Canadian dollars

 

 

2018

 

   

2017

 

 
    

 

Interest rate
swaps

 

   

 

Interest rate
swaps

 

 

 

Unrealized gain (loss) in interest expense, net

 

 

$

 

(1

 

 

 

$

 

2

 

 

Total gains (losses) in net income

 

  $

 

(1

 

 

  $

 

2

 

 

 

As at December 31, 2018, the Company had interest rate swaps in place for the $250 million non-revolving term credit facility in Brunswick Pipeline for interest payments through Q1 2019.

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, 2018, the maximum exposure the Company has to credit risk is $1,035 million (2017 - $1,148 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, 2018 was $346 million (2017 - $247 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, 2018, the Company had $118 million (2017 - $90 million) in financial assets, considered to be past due, which have been outstanding for an average 68 days. The fair value of these financial assets is $107 million (2017 - $78 million), the difference of which is included in the allowance for doubtful accounts. These assets primarily relate to accounts receivable from electric and gas revenue.

 

EMERA 2018 ANNUAL REPORT

110


NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

 

CONCENTRATION RISK

          

The Company’s concentrations of risk consisted of the following:

 

 

  
As at    December 31, 2018     December 31, 2017
     millions of
Canadian
dollars
     % of total
exposure
   

millions of

Canadian

dollars

    

% of total

exposure

Receivables, net

          

Regulated utilities

          

Residential

   $ 384        28   $ 326      23%

Commercial

     182        13     161      11%

Industrial

     57        4     46      3%

Other

     84        6     96      7%
       707        51     629      44%

Trading group

          

Credit rating of A- or above

     49        4     55      4%

Credit rating of BBB- to BBB+

     70        5     61      4%

Credit rating of CCC- to CCC+

     8        0          0%

Not rated

     108        8     96      7%
       235        17     212      15%

Other accounts receivable

     273        20     300      22%
       1,215        88     1,141      81%

Derivative Instruments (current and long-term)

          

Credit rating of A- or above

     130        9     207      15%

Credit rating of BBB- to BBB+

     9        1     10      1%

Not rated

     28        2     36      3%
       167        12     253      19%
     $ 1,382        100   $   1,394      100%

CASH COLLATERAL

The Company’s cash collateral positions consisted of the following:

 

As at

millions of Canadian dollars

              
December 31
2018
 
 
   December 31 2017

Cash collateral provided to others

             $ 103      $        119

Cash collateral received from others

               77      99

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, 2018, the total fair value of these derivatives, in a liability position, was $365 million (December 31, 2017 – $310 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 2018 ANNUAL REPORT

111


NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

 

13. FAIR VALUE MEASUREMENTS

The Company is required to determine the fair value of all derivatives except those which qualify for the NPNS exemption (refer to 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.

 

EMERA 2018 ANNUAL REPORT

112


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, 2018

 

millions of Canadian dollars

 

         

 

Level 1

 

   

 

Level 2

 

           

 

Level 3

 

    

 

Total

 

Assets

                                                

Regulatory deferral

                

Commodity swaps and forwards

                

Coal purchases

   $              $           70      $               $            70

Power purchases

        2                      2

Natural gas purchases and sales

              2                2

Heavy fuel oil purchases

              1                1

Foreign exchange forwards

                    29                      29
                2       102                      104

HFT derivatives

                

Power swaps and physical contracts

        2       2           3      7

Natural gas swaps, futures, forwards, physical contracts and related transportation

              1       36                 18      55
              3     38              21      62

Other derivatives

                

Interest rate swap

                    1                      1
                      1                      1

Total assets

              5       141                 21      167

Liabilities

                

Cash flow hedges

                

Foreign exchange forwards

                    5                      5
                      5                      5

Regulatory deferral

                

Commodity swaps and forwards

                

Coal purchases

              1                1

Power purchases

        1                      1

Heavy fuel oil purchases

              1                1

Natural gas purchases and sales

              3                            3
                4       2                      6

HFT derivatives

                

Power swaps and physical contracts

        14       6           1      21

Natural gas swaps, futures, forwards and physical contracts

                    28                 305      333
              14     34              306      354

Total liabilities

              18       41                 306      365

Net assets (liabilities)

    

$

       (13     $        100       

$

       (285)      $        (198)

 

EMERA 2018 ANNUAL REPORT

113


NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

 

As at                   December 31, 2017    

millions of Canadian dollars

 

  

Level 1

 

   

Level 2

 

    

Level 3

 

   

Total  

 

 

 

Assets

         

Cash flow hedges

         

Power swaps

   $ 5     $      $     $ 5    

Foreign exchange forwards

           2              2    
       5       2              7    

Regulatory deferral

         

Commodity swaps and forwards

         

Coal purchases

           127              127    

Power purchases

     5                    5    

Natural gas purchases and sales

           5              5    

Heavy fuel oil purchases

     4       8              12    

Foreign exchange forwards

           32              32    
       9       172              181    

HFT derivatives

         

Power swaps and physical contracts

           3        9       12    

Natural gas swaps, futures, forwards, physical contracts and related transportation

           26        25       51    
             29        34       63    

Other derivatives

         

Interest rate swap

           2              2    
           2              2    

Total assets

     14       205        34       253    

Liabilities

         

Cash flow hedges

         

Power swaps

     2                    2    

Foreign exchange forwards

           5              5    
       2       5              7    

Regulatory deferral

         

Power purchases

     3                    3    

Natural gas purchased and sales

     5       1              6    

Foreign exchange forwards

           4              4    
       8       5              13    

HFT derivatives

         

Power swaps and physical contracts

     49       5        (4     50    

Natural gas swaps, futures, forwards and physical contracts

     6       47        187       240    
       55       52        183       290    

Total liabilities

     65       62        183       310    

Net assets (liabilities)

   $         (51   $         143      $         (149   $         (57)   

The change in the fair value of the Level 3 financial assets for the year ended December 31, 2018 was as follows:    

 

             HFT Derivatives    

millions of Canadian dollars

 

  

Power

 

   

Natural gas

 

   

Total  

 

 

Balance, January 1, 2018

   $ 9     $         25     $         34   

Total realized and unrealized gains (losses) included in non-regulated operating revenues

             (6     (7     (13)  

Balance, December 31, 2018

   $ 3     $ 18     $ 21   

 

EMERA 2018 ANNUAL REPORT

114


NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

 

The change in the fair value of the Level 3 financial liabilities for the year ended December 31, 2018 was as follows:

 

                     HFT Derivatives    

 

millions of Canadian dollars

 

  

 

Power

 

   

 

Natural gas

 

    

 

Total  

 

 

Balance, January 1, 2018

   $           (4   $         187      $       183    

Total realized and unrealized gains (losses) included in non-regulated operating revenues

     5       118        123    

Balance, December 31, 2018

   $ 1     $ 305      $ 306    

The Company evaluates the observable inputs of market data on a quarterly basis in order to determine if transfers between levels is appropriate. For the year ended December 31, 2018, there were no transfers between levels.

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. Where possible, Emera also sources multiple broker prices in an effort to evaluate and substantiate these unobservable inputs. 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.

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, 2018  

 

 

millions of Canadian dollars

 

  

 

Fair
Value

 

   

 

Valuation
Technique

 

   

 

Unobservable Input

 

    

 

Range

 

      

 

Weighted  
average  

 

 

Assets

                

HFT derivatives -

   $ 3       Modelled pricing     Third-party pricing        $24.31 – $50.29          $31.43    

Power swaps and

       Probability of default        0.03% – 0.13%          0.13%    

physical contracts

       Discount rate        0.03% – 2.19%          1.45%    
                     Correlation factor        84.98% – 84.98%          84.98%    

HFT derivatives -

     8       Modelled pricing     Third-party pricing        $1.80 – $12.21          $4.75    

Natural gas swaps, futures,

       Probability of default        0.01% – 2.94%          0.24%    

forwards, physical contracts

       Discount rate        0.01% – 30.62%          4.25%    

and related transportation

     10       Modelled pricing     Third-party pricing        $1.95 – $12.90          $8.68    
       Basis adjustment        $0.07 – $3.43          $1.88    
       Probability of default        0.01% – 3.20%          0.57%    
       Discount rate        0.01% – 7.61%          0.42%    

Total assets

   $ 21                                    

Liabilities

                

HFT derivatives -

   $ 1       Modelled pricing     Third-party pricing        $20.80 – $50.29          $26.38    

Power swaps and

       Probability of default        0.08% – 0.29%          0.15%    

physical contracts

       Discount rate        0.03% – 2.99%          1.65%    
                     Correlation factor        84.98% – 84.98%          84.98%    

HFT derivatives -

     286       Modelled pricing     Third-party pricing        $1.48 – $12.90          $5.75    

Natural gas swaps, futures,

       Own credit risk        0.01% – 2.94%          0.09%    

forwards and physical contracts

       Discount rate        0.01% – 11.96%          2.35%    
     19       Modelled pricing     Third-party pricing        $2.15 – $13.18          $7.54    
       Basis adjustment        $0.07 – $3.43          $2.67    
       Own credit risk        0.01% – 2.76%          0.10%    
       Discount rate        0.01% – 7.61%          1.38%    

Total liabilities

   $ 306                                    

Net assets (liabilities)

   $       (285                                  

 

EMERA 2018 ANNUAL REPORT

115


NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

 

As at                       December 31, 2017    

 

millions of Canadian dollars

 

  

 

Fair
Value

 

   

 

Valuation
Technique

 

   

 

Unobservable Input

 

    

 

Range

 

      

 

Weighted  
average  

 

 

Assets

                

HFT derivatives -

   $ 1      

Modelled pricing

    Third-party pricing        $24.88 – $117.90          $92.93    

Power swaps and

       Probability of default        0.00% – 0.01%          0.00%    

physical contracts

       Discount rate        0.00% – 0.13%          0.00%    
     8      

Modelled pricing

    Third-party pricing        $63.48 – $117.00          $102.68    
       Correlation factor        0.94% – 0.99%          0.96%    
       Probability of default        0.00% – 0.00%          0.00%    
                     Discount rate        0.00% – 0.00%          0.00%    

HFT derivatives -

     18      

Modelled pricing

    Third-party pricing        $2.06 – $8.24          $3.61     

Natural gas swaps, futures,

       Probability of default        0.00% – 0.05%          0.00%    

forwards, physical contracts

       Discount rate        0.00% – 0.29%          0.06%    

and related transportation

     7      

Modelled pricing

    Third-party pricing        $2.04 – $12.52          $6.42     
       Basis adjustment        0.08% – 0.71%          0.52%    
       Probability of default        0.00% – 0.00%          0.00%    
       Discount rate        0.00% – 0.09%          0.01%    

Total assets

   $ 34                                    

Liabilities

                

HFT derivatives -

     (6    

Modelled pricing

    Third-party pricing        $24.88 – $117.90          $95.46    

Power swaps and

       Own credit risk        0.00% – 0.01%          0.00%    

physical contracts

       Discount rate        0.00% – 0.13%          0.00%    
     2      

Modelled pricing

    Third-party pricing        $94.5 – $117.00          $105.52    
       Correlation factor        0.94% – 0.99%          0.96%    
       Probability of default        0.00% – 0.00%          0.00%    
       Discount rate        0.00% – 0.00%          0.00%    

HFT derivatives -

     172      

Modelled pricing

    Third-party pricing        $1.89 – $11.81          $4.64    

Natural gas swaps, futures,

       Own credit risk        0.00% – 0.00%          0.00%    

forwards and physical contracts

       Discount rate        0.00% – 0.12%          0.02%    
     15      

Modelled pricing

    Third-party pricing        $2.15 – $12.52          $8.94    
       Basis adjustment        0.08% – 0.71%          0.53%    
       Own credit risk        0.00% – 0.00%          0.00%    
       Discount rate        0.00% – 0.08%          0.01%    

Total liabilities

   $ 183                                    

Net assets (liabilities)

   $         (149                                  

The financial assets and liabilities included on the Consolidated Balance Sheets that are not measured at fair value consisted of the following:

 

As at

 

                                         

millions of Canadian dollars

 

  

 

Carrying
Amount

 

    

Fair Value

 

    

Level 1

 

    

Level 2

 

    

Level 3

 

    

Total  

 

 

December 31, 2018

   $   15,411      $   15,908      $      $ 14,991      $ 917      $ 15,908    

December 31, 2017

   $ 13,881      $ 15,217      $           69      $     14,346      $         802      $     15,217    

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 loss of $122 million was recorded in Other Comprehensive Income for the year ended December 31, 2018 (2017 – $97 million gain after-tax). There was no ineffectiveness for the year ended December 31, 2018 (2017 – nil).

 

EMERA 2018 ANNUAL REPORT

116


NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

 

14. REGULATORY ASSETS AND LIABILITIES

Regulatory assets represent 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 appropriate 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
2018
     December 31
2017
 

Regulatory assets

     

Deferred income tax regulatory assets

   $ 775      $ 667  

Pension and post-retirement medical plan (1)

     453        380  

Cost recovery clauses

     75        17  

Environmental remediations

     31        41  

Hurricane Matthew restoration

     28        28  

Stranded cost recovery

     28        25  

Unamortized defeasance costs

     26        32  

Demand side management (“DSM”) deferral

     24        28  

Deferrals related to derivative instruments

     10        15  

Storm reserve

     4        59  

Other

     115        119  
     $     1,569      $     1,411  

Current

   $ 165      $ 138  

Long-term

     1,404        1,273  

Total regulatory assets

   $ 1,569      $ 1,411  

Regulatory liabilities

     

Deferred income tax regulatory liabilities

     1,218        1,116  

Accumulated reserve - cost of removal

     955        894  

Regulated fuel adjustment mechanism

     161        177  

Deferrals related to derivative instruments

     116        182  

Storm reserve

     76         

Cost recovery clauses

     30        51  

Self-insurance fund (note 31)

     30        28  

Other

     24        20  
     $ 2,610      $ 2,468  

Current

   $ 251      $ 226  

Long-term

     2,359        2,242  

Total regulatory liabilities

   $ 2,610      $ 2,468  

 

(1)

The December 31, 2017 pension and post-retirement medical plan regulatory asset includes a prior period reclassification of $35 million from AOCI, for changes in unrecognized pension and post-retirement benefit costs to be consistent with current year presentation. Refer to note 10 for further details.

 

EMERA 2018 ANNUAL REPORT

117


NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

 

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 rates, a regulatory asset or liability is recognized, unless specifically directed otherwise by a regulator.

In 2017, as a result of enactment of the US Tax Cuts and Jobs Act of 2017, the Company revalued its United States deferred income tax assets and liabilities based on the new 21 per cent tax rate. The Company reduced its US regulated net deferred income tax liabilities by $1.1 billion and recorded an equivalent regulatory liability since the benefit of lower US taxes is expected to be returned to customers over time as required by the Act or by order of the applicable regulator.

Pension and Post-Retirement Medical Plan

This asset is primarily related to the deferred costs of pension and post-retirement benefits at Emera Florida and New Mexico, and Emera Maine. It is included in rate base and earns a rate of return as permitted by the FPSC, New Mexico Public Regulation Commission (“NMPRC”) and Maine Public Utilities Commission (“MPUC”), as applicable. It is amortized over the remaining service life of plan participants.

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 the next year.

Environmental Remediations

This asset is primarily related to PGS costs associated with the environmental remediation at Manufactured Gas Plant (“MGP”) 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.

Hurricane Matthew Restoration

This asset represents restoration costs incurred by GBPC in 2016 associated with Hurricane Matthew. The asset is being amortized over five years and is included in rate base. The Grand Bahama Port Authority (“GBPA”) has approved full recovery of these storm restoration costs.

Stranded Cost Recovery

Due to the decommissioning of a GBPC steam turbine during 2012, the GBPA approved the recovery of a $21 million USD stranded cost through electricity rates; it is included in rate base for 2018 and 2017 and is expected to be included in future years.

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, 2018, totalled $759 million (2017 –$726 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 Nova Scotia Utility and Review Board (“UARB”).

DSM Deferral

The UARB approved the implementation of the 2015 DSM deferral set at $35 million for 2015 and recoverable from customers over an eight year period beginning in 2016.

The UARB directed EfficiencyOne to review the 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. As NSPI collects the associated amounts from customers over the next six 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.

 

EMERA 2018 ANNUAL REPORT

118


NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

 

Deferrals Related to Derivative Instruments

Tampa Electric, PGS, NMGC, NSPI and GBPC defer 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 the respective regulators. The realized gain or loss is recognized when the hedged item settles in regulated fuel for generation and purchased power, inventory or property, plant and equipment, depending on the nature of the item being economically hedged. Tampa Electric deferrals related to derivative instruments are recovered through cost-recovery mechanisms on a dollar-for-dollar basis in the year following the settlement of the derivative position.

Accumulated Reserve - Cost of Removal

This regulatory liability represents the non-ARO COR reserve in Tampa Electric 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.

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 are deferred to a fuel adjustment mechanism (“FAM”) regulatory asset or liability and recovered from or returned to customers in a subsequent year. For the years 2017 to 2019, differences between actual fuel costs and fuel revenues recovered from customers will be recovered or returned to customers after 2019, as required under the Electricity Plan Implementation (2015) Act, (“Electricity Plan Act”).

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.

On September 10, 2017, Tampa Electric was impacted by Hurricane Irma and incurred total restoration costs of approximately $102 million USD. The amount charged to the storm reserve exceeded the balance in the reserve by $47 million USD, which was recorded as a regulatory asset on the balance sheet. This regulated asset was included in rate base. On December 28, 2017, Tampa Electric petitioned the FPSC for recovery of estimated restoration costs in excess of the storm reserve for several named storms and to replenish the reserve to the $56 million USD level that existed at October 31, 2013. On March 1, 2018, the FPSC approved a settlement agreement authorizing the utility to net the amount of storm cost recovery against its return of estimated 2018 US tax reform benefits to customers, effective April 1, 2018. At December 31, 2018, Tampa Electric’s storm reserve liability was $56 million USD.

REGULATORY ENVIRONMENTS

Emera Florida and New Mexico

Tampa Electric and PGS are regulated separately by the FPSC. Tampa Electric is also subject to regulation by the FERC. In general, the FPSC sets rates at a level that allows utilities such as Tampa Electric and PGS to collect total revenues or revenue requirements equal to their cost of providing service, plus an appropriate return on invested capital.

NMGC is subject to regulation by the NMPRC. The NMPRC sets rates at a level that allows NMGC to collect total revenues equal to their cost of providing service, plus an appropriate return on invested capital.

 

EMERA 2018 ANNUAL REPORT

119


NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

 

Tampa Electric

Tampa Electric’s approved regulated return on equity (“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.

Tampa Electric has a fuel recovery clause approved by the FPSC, allowing it 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.

In September 2017, Tampa Electric announced its intention to invest approximately $850 million USD over four years in new utility-scale solar photovoltaic projects across its service territory. On November 6, 2017, the FPSC approved a settlement agreement allowing a solar base rate adjustment (“SoBRA”) that provides for the recovery, upon in-service, of up to 600 MW of investments in utility-scale solar projects phased in from late 2018 through early 2021. On May 8, 2018, the FPSC approved Tampa Electric’s first SoBRA. This SoBRA represents 145 MW and $24 million USD annually in estimated revenue requirements and Tampa Electric began collecting these revenues in September 2018. On October 29, 2018, the FPSC approved Tampa Electric’s second SoBRA. This SoBRA represents 260 MW and $46 million USD annually in estimated revenue requirements and Tampa Electric began collecting these revenues in January 2019.

As discussed in the Storm Reserve section above, in September 2017, Tampa Electric was impacted by Hurricane Irma and incurred restoration costs in excess of the balance in its storm reserve. Tampa Electric petitioned the FPSC for recovery of estimated restoration costs in excess of the storm reserve for several named storms and to replenish the reserve. The FPSC approved a settlement agreement filed by Tampa Electric authorizing the utility to net the estimated amount of storm cost recovery against its return of estimated 2018 US tax reform benefits to customers, effective April 1, 2018. In Q1 2018, Tampa Electric recorded OM&G expense and a regulatory liability of $19 million USD to offset tax reform benefits. This deferral was amortized over the balance of the year as a credit against recognition of storm expense. In total, OM&G expense due to the allowed netting of the storm cost recovery with tax reform benefits, net of amortization of first quarter tax reform benefits, was approximately $103 million USD for the year ended December 31, 2018. Tampa Electric’s final storm costs subject to netting will be determined in a separate regulatory proceeding in 2019. Any difference will be trued up and returned to customers in 2020. 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.

PGS

The approved ROE range for PGS is 9.25 per cent to 11.75 per cent, based on an allowed equity capital structure of 54.7 per cent. Absent any rate case filing, the bottom of the range will increase to 9.75 per cent in 2021. An ROE of 10.75 per cent is 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 including a return on capital invested incurred in developing and implementing energy conservation programs. In 2012, the FPSC approved a new 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. 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. As part of the depreciation study settlement agreement approved by the FPSC in February 2017, the Cast Iron/Bare Steel clause was expanded to allow recovery of accelerated replacement of certain obsolete pipe.

 

EMERA 2018 ANNUAL REPORT

120


NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

 

On February 7, 2017, the FPSC approved a settlement agreement which resulted in new depreciation rates that reduce annual depreciation by $16 million USD and accelerate the amortization of the regulated asset related to the MGP environmental remediation costs. As part of the settlement, PGS and the Office of Public Counsel agreed that at least $32 million USD of PGS’s regulatory asset associated with the environmental liability for current and future remediation costs related to former MGP sites will be amortized over the period 2016 through 2020, with at least $21 million USD amortized over a two year recovery period beginning in 2016. In 2017 and 2016, PGS recorded $5 million USD and $16 million USD, respectively, of this amortization expense.

The 2017 PGS settlement agreement does not contain a provision for tax reform. On September 12, 2018, the FPSC approved a settlement agreement filed by PGS authorizing the utility to amortize $11 million USD of its MGP environmental regulatory asset and net it against its estimated 2018 tax reform benefits. Beginning in January 2019, PGS will lower base rates by $12 million USD to reflect the impact of tax reform and reduce depreciation rates by $10 million USD in accordance with the settlement agreement.

PGS is permitted to initiate a general base rate proceeding if it forecasts that ROE will fall below its allowed range.

NMGC

The approved ROE for NMGC is 10 per cent, on an allowed equity capital structure of 52 per cent. NMGC’s rates were established in a 2012 rate case settlement and were frozen until December 31, 2017 per the June 2016 NMPRC order (the “Order”) approving Emera’s acquisition of TECO Energy. NMGC filed a rate case, including the prospective impact of tax reform, on February 26, 2018. A hearing in the rate case was held on September 24, 2018, where an uncontested stipulation on the rate request was presented. A second hearing on the rate case related to 2018 tax reform benefits was held on December 17, 2018. As of December 31, 2018, NMGC recorded a regulatory liability of $8 million USD to reflect 2018 tax reform benefits. A decision by the NMPRC on the rate case and on 2018 tax reform benefits is expected in 2019.

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 2016, NMGC received approval of its PGAC Continuation Filing for the four-year period ending December 2020.

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 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 an appropriate return to investors. NSPI’s approved regulated ROE range for 2018 and 2017 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, which enables it to seek recovery of fuel costs through regularly scheduled 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.

The Electricity Plan Implementation (2015) Act, (“Electricity Plan Act”), was enacted by the Province of Nova Scotia in December 2015, which required NSPI to file a three-year stability plan for fuel costs and a General Rate Application (“GRA”) for non-fuel costs if required. In July 2016, the UARB approved a Consensus Agreement between NSPI and customer representatives related to the Rate Stability Plan for fuel costs for 2017 through 2019 which resulted in an average annual increase of 1.1 per cent for each of these three years. Subsequently, certain customer representatives requested changes resulting in amended rates that were approved by the UARB in November 2016 and result in an average annual rate increase of 1.5 per cent for each of these three years.

 

EMERA 2018 ANNUAL REPORT

121


NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

 

In September 2017, the UARB approved NSPI’s interim assessment payment to NSPML of the costs associated with the Maritime Link when it is in service. The Maritime Link entered service on January 15, 2018 and NSPI started paying the UARB approved interim assessment payments. As of December 31, 2018, $96 million has been paid to NSPML. The UARB approved annual payment for 2019 is $111 million. The payments are subject to a holdback of $10 million in each of 2018 and 2019 pending UARB agreement that a minimum of $10 million per year 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. As of December 31, 2018, NSPI has recorded a $2 million holdback payable to NSPML.

In response to the delayed timing of energy delivery from the Muskrat Falls project, the approved interim assessment payment reflects a $53 million reduction in NSPML’s assessment in each of 2018 and 2019, related to depreciation and amortization expenses. As these amounts are included in NSPI’s 2017, 2018 and 2019 fuel rates and are being recovered from customers, NSPI is providing a credit to customers, including interest, as the payments from NSPI to NSPML are not required in those years. In 2018, $17 million was refunded. The credit to customers will be approximately $36 million in 2019 and $53 million in 2020.

After 2019 and the Rate Stability Plan, the timing and amounts payable to NSPML and NSPI’s future rate recoveries of the Maritime Link costs will be subject to regulatory filings with the UARB, with expected filings in 2019 and 2020.

Emera Maine

Emera Maine’s distribution operations and stranded cost recoveries are regulated by the MPUC. The transmission operations are regulated by the FERC. Rates for these are established in distinct regulatory proceedings. US tax reform benefits, resulting from the lower tax rate, were reflected in distribution and transmission rates effective July 1, 2018, with other components being deferred to be addressed in future regulatory proceedings.

Distribution Operations

Emera Maine’s distribution businesses operate under a traditional cost-of-service regulatory structure, and distribution rates are set by the MPUC. In June 2018, the MPUC approved a 5.3 per cent distribution rate increase. This increase was effective July 1, 2018 and is based on a 9.35 per cent ROE and a common equity component of 49 per cent. Prior to July 1, 2018, the allowed ROE was 9.0 per cent, on a common equity component of 49 per cent.

Transmission Operations

Emera Maine’s transmission operations are split between two districts; Bangor Hydro District and Maine Public Service (“MPS”). Bangor Hydro District local transmission rates are regulated by the FERC and set annually on June 1, based on a formula utilizing prior year actual transmission investments, adjusted for current year forecasted transmission investments. The allowed ROE for Bangor Hydro District local transmission operations for 2018 and 2017 is 10.57 per cent. Bangor Hydro District’s bulk transmission assets are managed by ISO-New England (“ISO-NE”) as part of a region-wide pool of assets. The allowed ROE range for Bangor Hydro bulk transmission assets is 11.07 to 11.74 per cent for 2018 and 2017.

MPS District local transmission rates are regulated by the FERC and are set annually on June 1 for wholesale and July 1 for retail customers based on a formula utilizing prior year actual transmission investments and expenses. The current allowed ROE for transmission operations is 9.6 per cent (2017 – 9.6 per cent).

Stranded Cost Recoveries

Stranded cost recoveries in Maine are set by the MPUC. Electric utilities are permitted to recover all prudently incurred stranded costs resulting from the restructuring of the industry in 2000 that could not be mitigated or that arose as a result of rate and accounting orders issued by the MPUC.

 

EMERA 2018 ANNUAL REPORT

122


NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

 

The Barbados Light & Power Company Limited

BLPC is regulated by the Fair Trading Commission, 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.

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 2018 and 2017.

All BLPC fuel costs are passed to customers through the fuel pass-through mechanism which provides the opportunity to recover all fuel costs in a timely manner. The approved calculation of the fuel charge is adjusted monthly.

In December 2018, the Government of Barbados signed the Income Tax Amendment Act into law. This legislation which is 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.

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 flexible tariff adjustment policy to ensure that fuel costs are recovered and a reasonable return earned. GBPC’s approved regulated return on rate base was 8.5 per cent for 2018 (2017 – 8.8 per cent). In December 2018, the GBPA approved GBPC’s regulated return on rate base of 8.44 per cent for 2019.

In December 2016, the GBPA approved that over a five-year period, 2017 to 2021, the all-in rate for electricity (fuel and base rates) will be held at 2016 levels. 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 2018 and 2017.

Domlec fuel costs are passed to customers through a fuel pass-through mechanism which provides the opportunity to recover substantially all fuel costs in a timely manner.

Dominica experienced unprecedented damage as a result of Hurricane Maria in September 2017, reducing the customer base from approximately 36,000 to 26,000 at December 31, 2018. Many homes were destroyed and have not been rebuilt at this time. Domlec has fully restored power to all customers who request power and are able to receive it. Domlec maintains insurance for its generation fleet and, subsequent to Hurricane Maria, has obtained specialized insurance for its transmission and distribution networks.

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 pipeline is considered a Group II pipeline regulated by the National Energy Board (“NEB”). The NEB Gas Transportation Tariff is filed by Brunswick Pipeline in compliance with the requirements of the NEB Act and sets forth the terms and conditions of the transportation rendered by Brunswick Pipeline.

 

EMERA 2018 ANNUAL REPORT

123


NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

 

15. 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 $97 million for the year ended December 31, 2018 (2017 – nil). 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 $29 million for the year ended December 31, 2018 (2017 – $28 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, 2018 and at December 31, 2017.

16. RECEIVABLES AND OTHER CURRENT ASSETS

Receivables and other current assets consisted of the following:

 

As at

millions of Canadian dollars

   December 31
2018
    December 31
2017
 

Customer accounts receivable – billed

   $ 844     $ 805  

Customer accounts receivable – unbilled

     296       278  

Allowance for doubtful accounts

     (11     (12

Other receivables

     86       70  

Capitalized transportation capacity (1)

     179       89  

Income tax receivable

     175       24  

Prepaid expenses

     42       59  

Net investment in direct financing lease (note 20)

     9       8  

Due from related parties (note 15)

           5  
     $ 1,620     $ 1,326  
(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.

 

EMERA 2018 ANNUAL REPORT

124


NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

 

17. HELD FOR SALE

On November 26, 2018, Emera announced an agreement to sell its three NEGG facilities for $590 million USD plus a final working capital adjustment made on close. Proceeds from the sale of the NEGG facilities will be used to reduce corporate level debt and support capital investment opportunities within the regulated utility business. The transaction is expected to close in the first quarter of 2019 and is subject to certain regulatory approvals including approval of the FERC. The applicable provisions of the Hart-Scott-Rodino Antitrust Act have been satisfied.

As at December 31, 2018, the assets of the NEGG facilities were classified as held for sale and were measured at the lower of their carrying value or fair value less costs to sell. The measurement did not result in a fair value adjustment and the assets are no longer being depreciated. Included in assets held for sale on the Consolidated Balance Sheets was $777 million ($570 million USD) related to Property, plant and equipment. The NEGG operations are included within the Company’s Emera Energy segment.

18. PROPERTY, PLANT AND EQUIPMENT

Property, plant and equipment consisted of the following regulated and non-regulated assets:

 

As at
millions of Canadian dollars
  Estimated useful life      December 31
2018
    December 31
2017
 

Generation (1)

  3 to 131      $ 11,092     $ 11,010  

Transmission

  11 to 80        3,047       2,786  

Distribution

  4 to 80        6,348       5,660  

Gas transmission and distribution

  7 to 85        3,398       2,867  

General plant and other

  2 to 60        2,158       1,874  

Total cost

         26,043       24,197  

Less: Accumulated depreciation (1)

           (8,567     (7,824
         17,476       16,373  

Construction work in progress

           1,236       622  

Net book value

         $ 18,712     $ 16,995  

 

(1)

On November 26, 2018, the Company announced an agreement to sell the NEGG facilities and as of December 31, 2018, the Company has classified these assets as held for sale. As of December 31, 2017, these assets were recorded within Property, Plant and Equipment on the Consolidated Balance Sheets. Refer to note 17 for additional information.

 

EMERA 2018 ANNUAL REPORT

125


NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

 

19. 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, Maine, Connecticut, Massachusetts, Rhode Island, New Mexico, Barbados, Dominica and Grand Bahama Island.

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           2018            2017  
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

   $ 2,683     $ 356     $ 2,607     $ 358  

Service cost

     51       6       49       5  

Plan participant contributions

     8       5       8       4  

Interest cost

     95       13       99       14  

Benefits paid

     (143     (33     (129     (27

Actuarial (gains) losses

     (133     (25     171       25  

Settlements and curtailments

     (18           (35      

Foreign currency translation adjustment

     107       28       (87     (23

Balance, December 31

     2,650       350       2,683       356  

Change in plan assets

        

Balance, January 1

     2,408       45       2,208       39  

Employer contributions

     51       31       109       27  

Plan participant contributions

     8       5       8       4  

Benefits paid

     (143     (33     (129     (27

Actual return on assets, net of expenses

     (105     (3     313       5  

Settlements and curtailments

     (18           (34      

Foreign currency translation adjustment

     99       4       (67     (3

Balance, December 31

     2,300       49       2,408       45  

Funded status, end of year

   $ (350   $ (301   $ (275   $ (311

PLANS WITH PBO/APBO IN EXCESS OF PLAN ASSETS

The aggregate financial position for all pension plans where the PBO or, for post-retirement benefit plans, the APBO exceeds the plan assets for the years ended December 31 is as follows:

 

millions of Canadian dollars           2018            2017  
      Defined
benefit
pension plans
    Non-pension
benefit plans
    Defined
benefit
pension plans
    Non-pension
benefit plans
 

PBO/APBO

   $ 2,623     $ 318     $ 2,655     $ 325  

Fair value of plan assets

     2,264       6       2,370       6  

Funded status

   $ (359   $ (312   $ (285   $ (319

 

EMERA 2018 ANNUAL REPORT

126


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 $2,527 million as at December 31, 2018 (2017 – $2,561 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    2018     2017  
      Defined
benefit
pension plans
    Defined
benefit
pension plans
 

ABO

   $ 2,504     $ 1,608  

Fair value of plan assets

     2,264       1,409  

Funded status

   $ (240   $ (199

BALANCE SHEET

The amounts recognized in the Consolidated Balance Sheets consisted of the following:

 

As at
millions of Canadian dollars
          December 31
2018
           December 31
2017
 
      Defined
benefit
pension plans
    Non-pension
benefit plans
    Defined
benefit
pension plans
    Non-pension
benefit plans
 

Other current liabilities

     $ (12     $ (19     $ (23   $ (18

Long-term liabilities

     (347     (294     (264     (295

Other long-term assets

     9       11       10        

Amount included in deferred income tax

     5       (2     2        

AOCI, net of tax and regulatory assets

     628       60       561       74  

Net amount recognized

     $ 283       $ (244     $ 286     $ (239

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 (1)

         

Balance, January 1, 2018

      $ 315     $ 251     $ (3

Amortized in current period

        (26     (37     1  

Current year addition to AOCI or regulatory assets

        73       32        

Change in foreign exchange rate

              27              

Balance, December 31, 2018

            $ 389     $ 246     $ (2

Non-pension benefits plans (1)

         

Balance, January 1, 2018

      $ 78     $ (4   $  

Amortized in current period

        2       1        

Current year addition to AOCI or regulatory assets

        (17     (4      

Change in foreign exchange rate

              2              

Balance, December 31, 2018

            $ 65     $ (7   $  
(1)

The January 1, 2018 balances include a prior period reclassification from AOCI to Regulatory assets, for changes in unrecognized pension and post- retirement benefit costs to be consistent with current year presentation. Refer to notes 10 and 14 for further details.

 

EMERA 2018 ANNUAL REPORT

127


NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

 

             2018            2017  
    

 

 


 

 

Defined

benefit
pension plans

 

 

 


 

 

 

 

 

 

 

Non-pension
benefit plans

 

 

 
 

 

 

 

 

 

 

Defined
   benefit
pension plans

 

 


 
 

 

 

 

 

 

 

Non-pension
benefit plans

 

 

 
 

 

Actuarial losses

     $         246       $           (7 )      $         251       $           (4

Past service (gains) costs

     (2 )            (3      

Regulatory assets

 

    

 

389

 

 

 

   

 

65

 

 

 

   

 

315

 

 

 

   

 

78

 

 

 

Total AOCI and regulatory assets before deferred income taxes

 

     633       58       563       74  

Amount included in deferred income tax assets

 

    

 

(5

 

)  

 

   

 

2

 

 

 

   

 

(2

 

 

   

 

 

 

 

Net amount in AOCI and regulatory assets

     $          628       $           60       $         561       $          74  

BENEFIT COST COMPONENTS

Emera’s net periodic benefit cost included the following:

 

As at

                     Year ended December 31    

millions of Canadian dollars

 

            

 

2018

 

 

 

           

 

2017  

 

 

 

      

 

Defined
   benefit
pension plans

 


 
 

 

   

 

Non-pension
benefit plans

 

 
 

 

   

 

Defined
   benefit
pension plans

 


 
 

 

   

 

Non-pension  
benefit plans  

 

 
 

 

Service cost

     $            51       $              6       $             49       $             5    

Interest cost

     95       13       99       14    

Expected return on plan assets

     (138 )      (2 )      (129     (3)  

Current year amortization of:

        

Actuarial losses

     33       (1 )      38       2    

Past service costs (gains)

     (1 )                  (8)  

Regulatory assets (liability)

     26       (2 )      17       (1)  

Settlement, curtailments

     4             (1     –    

Total

 

    

 

$            70

 

 

 

   

 

$             14

 

 

 

   

 

$             73

 

 

 

   

 

$             9  

 

 

 

The expected return on plan assets is determined based on the market-related value of plan assets of $2,223 million as at January 1, 2018 (2017 – $2,153 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 basket 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 2018 ANNUAL REPORT

128


NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

 

Non-Canadian Pension Plans   
   Target Range at Market    
Asset Class    Weighted average    
Fixed income    48% to 53%    
Equities    47% to 52%    

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, 2018    
     

 

NAV

 

    

 

Level 1

 

   

 

Level 2

 

    

 

Total

 

   

 

Percentage

 

 

Cash and cash equivalents

     $            –        $            30       $            –        $            30       1

Net in-transits

            (56            (56     –2

Equity Securities:

            

Canadian equity

            191              191       8 % 

US equity

            330              330       14 % 

Other equity

            157              157       7 % 

Fixed income securities:

            

Government

                  119        119       5 % 

Corporate

                  108        108       5 % 

Other

            4       3        7       – 

Mutual funds

            132              132       6

Other

            8       4        12       1

Open-ended investments measured at NAV (1)

     820                     820       36

Common collective trusts measured at NAV (2)

     450                     450       19

Total

    

$    1,270

       $         796       $        234        $        2,300       100

millions of Canadian dollars

                               December 31, 2017    
     

 

NAV

 

    

 

Level 1

 

   

 

Level 2

 

    

 

Total

 

   

 

Percentage

 

 

Cash and cash equivalents

     $             –        $           32       $            –        $            32       1

Net in-transits

            (36            (36     –1

Equity Securities:

            

Canadian equity

            214              214       9

US equity

            390              390       16

Other equity

            197              197       8

Fixed income securities:

            

Government

                  72        72       3

Corporate

                  56        56       2

Other

            5              5       – 

Mutual funds

            246              246       10

Other

                  4        4       – 

Open-ended investments measured at NAV (1)

     819                     819       34

Common collective trusts measured at NAV (2)

     409                     409       18

Total

     $     1,228        $     1,048       $        132        $        2,408       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 13 for more information on the fair value hierarchy and inputs used to measure fair value.

 

EMERA 2018 ANNUAL REPORT

129


NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

 

POST-RETIREMENT BENEFIT PLANS

There are no assets set aside to pay for the Canadian post-retirement benefit plans. As is common in Canada, post-retirement health benefits are paid from general accounts as required.

INVESTMENTS IN EMERA

As at December 31, 2018 and 2017, 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

 

        

2019

                         $ 53      $ 22  

Expected benefit payments

 

        

2019

             149        24  

2020

             152        25  

2021

             162        25  

2022

             169        25  

2023

             175        26  

2024 – 2028

                       988        127  

 

ASSUMPTIONS

 

The following table shows the assumptions that have been used in accounting for defined benefit pension and other post-retirement benefit plans:

 

 

 

                   2018              2017  
(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

     4.05%        4.30%        3.55%        3.65%  

Rate of compensation increase

     3.30%        3.67%        3.12%        3.28%  

Health care trend - initial (next year)

            6.39%               6.65%  
             - ultimate             4.45%               4.45%  
   

           - year ultimate reached

            2035               2036  

Benefit cost for year ended December 31:

           

Discount rate

     3.55%        3.65%        3.96%        4.18%  

Expected long-term return on plan assets

     6.38%        3.73%        6.29%        6.08%  

Rate of compensation increase

     3.12%        3.28%        2.82%        2.54%  

Health care trend - initial (current year)

            6.65%               6.78%  

                              - ultimate

            4.45%               4.45%  

                              - year ultimate reached

            2036               2035  

Figures shown are weighted averages. 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 2018 ANNUAL REPORT

130


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.

SENSITIVITY ANALYSIS FOR NON-PENSION BENEFITS PLANS

The health care cost trend significantly influences the amounts presented for health care plans. An increase or decrease of one percentage point of the assumed health care cost trend would have had the following impact in 2018:

 

millions of Canadian dollars

 

       

Increase

 

         

Decrease

 

 

Service cost and interest cost

   $     1      $     (1

Accumulated post-retirement benefit obligation, December 31

         17            (15

SENSITIVITY ANALYSIS FOR DEFINED BENEFIT PENSION PLANS

The impact on the 2018 benefit cost of a 25 basis point change in the discount rate and asset return assumptions is as follows:

 

millions of Canadian dollars

 

       

Increase

 

        

Decrease

 

 

Discount rate assumption

   $     (9   $     9  

Asset rate assumption

         (6         6  

AMOUNTS TO BE AMORTIZED IN THE NEXT FISCAL YEAR

The following table shows the amounts from the AOCL and regulatory assets, which are expected to be recognized as part of the net periodic benefit cost in fiscal 2019:

 

millions of Canadian dollars

 

 

Defined
benefit
pension plans

 

   

Non-pension
benefit plans

 

 

Actuarial gains (losses)

  $ (15   $ (1

Past service gains

    1       6  

Regulatory assets

    (16     2  

Total

  $ (30   $ 7  

DEFINED CONTRIBUTION PLAN

Emera also provides a defined contribution pension plan for certain employees. The Company’s contribution for the year ended December 31, 2018 was $31 million (2017 – $23 million).

20. NET INVESTMENT IN DIRECT FINANCING LEASE

Emera’s net investment in direct financing lease primarily relates to Brunswick Pipeline. The agreement meets the definition of a direct financing capital lease for accounting purposes. The net investment in direct financing lease consists of the sum of the minimum lease payments and residual value net of estimated executory costs and unearned income. The 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. Net investment in direct financing lease consists of the following:

 

As at

millions of Canadian dollars

  December 31
2018
    December 31
2017
 

Total minimum lease payments to be received

  $ 1,066     $ 1,126  

Less: amounts representing estimated executory costs

    (201     (211

Minimum lease payments receivable

  $ 865     $ 915  

Estimated residual value of leased property (unguaranteed)

    183       183  

Less: unearned finance lease income

    (564     (609

Net investment in direct financing lease

  $ 484     $ 489  

Principal due within one year (included in Receivables and other current assets)

    9       8  

Net investment in direct financing lease - long-term

  $ 475     $ 481  

 

EMERA 2018 ANNUAL REPORT

131


NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

 

Future minimum lease payments to be received for the next five years:    

 

For the                               Year ended December 31  

millions of Canadian dollars

 

  

2019

 

   

2020

 

   

2021

 

         

2022

 

         

2023

 

 

Minimum lease payments to be received

   $ 65     $ 65     $ 65     $      65     $      64  

Less: amounts representing estimated executory costs

     (12     (12     (12        (12        (12
               

Minimum lease payments receivable

   $         53     $         53     $         53     $      53     $      52  

21. GOODWILL

The change in goodwill for the year ended December 31 is due to the following:    

 

millions of Canadian dollars

 

  

2018

 

    

2017

 

 

Balance, January 1

   $       5,805      $       6,213  

Change in foreign exchange rate

     508        (408
     

Balance, December 31

   $ 6,313      $ 5,805  

Goodwill on Emera’s Consolidated Balance Sheets relates to the acquisitions of TECO Energy, Emera Maine and GBPC. Goodwill is subject to an annual assessment for impairment at the reporting unit level. Emera’s reporting units with goodwill are Tampa Electric, PGS, New Mexico Gas, Emera Maine and GBPC.

A qualitative impairment assessment was performed for Tampa Electric, PGS, New Mexico Gas, Emera Maine and GBPC, concluding that the fair value of the reporting units exceeded their respective carrying values, and as such, no quantitative assessments were performed and no impairment charges were recognized.

22. 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    2018      Weighted
average
interest rate
     2017      Weighted
average
interest rate
 

TECO Finance

           

Advances on revolving credit and term facilities

   $ 805        3.43%      $ 820        2.58%  

Tampa Electric Company

           

Advances on accounts receivable and revolving credit facilities

     302        3.10%        382        2.07%  

NMGC

           

Advances on revolving credit facilities

     79        3.40%        38        2.47%  

NSPI

           

Bank indebtedness

     –          –%        1        –%  

Short-Term debt

   $     1,186               $     1,241           

 

EMERA 2018 ANNUAL REPORT

132


NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

 

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      2018      2017    

TECO Energy/TECO Finance – term credit facility

     2019      $         682      $         502    

TECO Energy/TECO Finance – revolving credit facility

     2022        546        376    

Tampa Electric Company – revolving credit facility

     2022        443        408    

Tampa Electric Company – accounts receivable revolving credit facility

     2021        205        188    

Tampa Electric Company – term loan

     2018               377    

NMGC – revolving credit facility

     2022        171        157    

GBPC – revolving credit facility

     2019        18        16    
       

Total

              2,065        2,024    

Less:

        

Advances under revolving credit and term facilities

        1,186        1,241    

Letters of credit issued within the credit facilities

        3        3    
       

Total advances under available facilities

        1,189        1,244    
       

Available capacity under existing agreements

            $ 876      $ 780    

The weighted average interest rate on outstanding short-term debt at December 31, 2018 was 3.34 per cent (2017 – 2.42 per cent).

RECENT FINANCING ACTIVITY

Emera Florida and New Mexico

On October 11, 2018, TEC repaid a $300 million USD 1-year term credit facility using proceeds from a senior note issuance. Refer to note 24.

On March 23, 2018, TEC extended the maturity date of its $150 million USD accounts receivable collateralized borrowing facility from March 23, 2018 to March 22, 2021. There were no other changes in commercial terms.

On March 7, 2018, TECO Energy/Finance increased its $300 million USD revolving credit facility by $100 million USD to $400 million USD. There were no other changes in commercial terms.

On March 7, 2018, TECO Energy/Finance increased its $400 million USD term bank credit facility by $100 million USD to $500 million USD, and extended the maturity date to March 8, 2019. There were no other changes in commercial terms.

23. OTHER CURRENT LIABILITIES

Other current liabilities consisted of the following:

 

As at

millions of Canadian dollars

   December 31
2018
     December 31  
2017  
 

Accrued charges

   $         154      $         134    

Accrued interest on long-term debt

     93        78    

Pension and post-retirement liabilities (note 19)

     31        41    

Sales and other taxes payable

     9        11    

Emission credits obligations (1)

     8        21    

Income tax payable

     6        1    

Other

     127        64    
     
     $ 428      $ 350    

 

(1)

Throughout the three-year compliance period associated with the Regional Greenhouse Gas Initiative for carbon dioxide emissions, an obligation is recognized as gas is burned, measured at the cost to acquire credits for the related emissions. Emission credits are capitalized to inventory (note 11) when purchased and subsequently applied against the emission liabilities at the end of each compliance period.

 

EMERA 2018 ANNUAL REPORT

133


NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

 

24. 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.

Long-term debt as at December 31, 2018, consisted of the following:

 

    

Weighted average                  

interest rate (1)    

               
millions of Canadian dollars    2018      2017      Maturity      2018      2017    

Emera

              

Bankers acceptances, LIBOR loans

     Variable        Variable        2020      $ 339      $ 133    

Unsecured fixed rate notes

     3.50%        3.50%        2019–2023        725        725    

Fixed to floating subordinated notes (USD)

     6.75%        6.75%        2076        1,637        1,505    
                                $ 2,701      $ 2,363    

Emera US Finance LP

              

Unsecured senior notes (USD)

     3.60%        3.60%        2019–2046      $ 4,434      $ 4,077    

TECO Finance (2)

              

Variable rate notes (USD)

        Variable        2018      $ -      $ 314    

Fixed rate notes and bonds (USD)

     5.15%        5.15%        2020        409        376    
                                $ 409      $ 690    

Tampa Electric (3)

              

Fixed rate notes and bonds (USD)

     4.64%        4.75%        2021–2049      $       3,126      $       2,410    

PGS

              

Fixed rate notes and bonds (USD)

     4.66%        5.06%        2021–2049      $ 425      $ 328    

NMGC

              

Fixed rate notes and bonds (USD)

     4.53%        4.53%        2021–2026      $ 368      $ 339    

NMGI

              

Fixed rate notes and bonds (USD)

     3.41%        3.41%        2019–2024      $ 273      $ 251    

NSPI

              

Discount notes

     Variable        Variable        2023      $ 516      $ 364    

Medium term fixed rate notes

     5.73%        5.73%        2025–2097        1,965        1,965    

Fixed rate debenture

     9.75%        9.75%        2019        95        95    
                                $ 2,576      $ 2,424    

Emera Maine

              

LIBOR loans and demand loans

     Variable        Variable        2023      $ 28      $ 51    

Secured fixed rate mortgage bonds (USD)

     9.74%        9.74%        2020–2022        68        63    

Unsecured senior fixed rate notes (USD)

     4.23%        4.15%        2022–2048        382        294    
                                $ 478      $ 408    

EBP

              

Senior secured credit facility

     3.08%        3.08%        2022      $ 248      $ 248    

GBPC

              

Amortizing fixed rate notes (USD)

     3.83%        3.77%        2021–2022      $ 114      $ 78    

Senior notes (USD)

     7.07%        7.07%        2020–2023        68        88    
                                $ 182      $ 166    

 

EMERA 2018 ANNUAL REPORT

134


NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

 

(continued)                                  
    

Weighted average                  

interest rate (1)    

              

millions of Canadian dollars

 

  

2018

 

    

2017

 

    

Maturity

 

    

2018

 

   

2017  

 

 

ICDU

             

Fixed rate note (USD)

     4.00%               2023      $ 24     $ –    

BLPC & ECI

             

Secured senior notes (USD)

     Variable        Variable        2021        159       168    

Secured fixed rate senior notes (4)

     4.74%        5.06%        2020 –2035      $ 99     $ 76    
                                $ 258     $ 244    

Adjustments

             

Fair market value adjustment – TECO Energy acquisition (5)

            $ 22     $ 31    

Debt issuance costs

              (113     (98)    

Amount due within one year

                                (1,119     (741)    
                                $ (1,210   $ (808)    

Long-Term Debt

                              $         14,292     $         13,140    

 

(1)

Weighted average interest rate of fixed rate long-term debt.

(2)

TECO Energy is a full and unconditional guarantor of TECO Finance’s securities, and no subsidiaries of TECO Energy guarantee TECO Finance’s securities.

(3)

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.

(4)

Notes are issued and payable in either USD, BBD or East Caribbean Dollar (XCD).

(5)

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.

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      2018      2017    

Emera – revolving credit facility (1)

     June 2020      $ 900      $ 900    

NSPI – revolving credit facility (1)

     October 2023        600        600    

Emera Maine – revolving credit facility

     February 2023        109        100    

BLPC – revolving credit facility

     2021 – 2022        26        24    

Total

                       1,635        1,624    

Less:

        

Borrowings under credit facilities

        899        598    

Letters of credit issued inside credit facilities

              77        44    

Use of available facilities

              976        642    

Available capacity under existing agreements

            $ 659      $          982    

 

(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:

 

      Financial Covenant      Requirement     

As at  

December 31, 2018  

 

Emera

        

Syndicated credit facilities

     Debt to capital ratio        Less than or equal to 0.70 to 1        0.60 : 1    

 

EMERA 2018 ANNUAL REPORT

135


NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

 

RECENT FINANCING ACTIVITY

Emera

On May 16, 2018, Emera filed a $750 million debt and preferred equity shelf prospectus, providing the Company with access to raise long-term debt and preferred equity. On May 31, 2018, preferred shares were issued under this base shelf prospectus for gross proceeds of $300 million (refer to note 27). As at December 31, 2018 the Company has $450 million available for issuance under this prospectus, which expires on June 16, 2020.

Emera Florida and New Mexico

On October 4, 2018, TEC completed a $375 million USD 30-year senior notes issuance. The notes bear interest at a rate of 4.45 per cent and have a maturity date of June 15, 2049. Proceeds from this issuance were used to repay a $300 million USD 1-year term credit facility. Refer to note 22.

On June 7, 2018, TEC completed a $350 million USD 30-year senior notes issuance. The notes bear interest at a rate of 4.30 per cent and maturity date of June 15, 2048.

On April 10, 2018, TECO Energy/Finance repaid a $250 million USD note upon maturity. The note was repaid using funds from existing credit facilities and cash on hand.

NSPI

On October 31, 2018, NSPI amended its operating credit facility to extend the maturity from October 2021 to October 2023. There were no other changes in commercial terms.

Emera Maine

On November 15, 2018, Emera Maine completed a $50 million USD 30-year senior notes issuance. The notes bear interest at a rate of 4.71 per cent and will mature on November 15, 2048. Proceeds from this issuance were used for general corporate purposes.

On February 28, 2018, Emera Maine extended the maturity date of its $80 million USD operating credit facility from September 25, 2019 to February 28, 2023. There were no other changes in commercial terms.

ECI

On January 12, 2018, a wholly owned indirect subsidiary of ECI entered into a five year $18 million Bahamian dollar loan agreement with an interest rate of 4.00 per cent and maturity date of January 12, 2023.

EBP

On October 31, 2018, Emera Brunswick Pipeline amended its Credit Agreement to extend the maturity from February 2021 to February 2022. There were no other changes in commercial terms.

 

EMERA 2018 ANNUAL REPORT

136


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

 

  

2019

 

    

2020

 

    

2021

 

    

2022

 

    

2023

 

    

Thereafter

 

    

Total

 

 

 

Emera

   $         225      $         339      $           –      $       –      $       500      $       1,637      $       2,701  

Emera US Finance LP

     682               1,023                      2,729        4,434  

TECO Finance

            409                                    409  

Tampa Electric

                   315        307               2,504        3,126  

PGS

                   64        34               327        425  

NMGC

                   273                      95        368  

NMGI

     69                                    204        273  

NSPI

     95                             516        1,965        2,576  

Emera Maine

            41               123        28        286        478  

EBP

                          248                      248  

GBPC

     17        50        37        33        45               182  

ICDU

                                 24               24  

BLPC & ECI

     31        59        30        13        25        100        258  

Total

   $ 1,119      $ 898      $ 1,742      $ 758      $ 1,138      $ 9,847      $ 15,502  

25. ASSET RETIREMENT OBLIGATIONS

AROs mostly relate to the 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

 

  

2018

 

   

2017

 

 

 

Balance, January 1

   $         172     $         170  

Additions (1)

     25       2  

Liabilities settled

     (2     (3

Accretion included in depreciation expense

     6       6  

Other

     (1     1  

Change in foreign exchange rate

     5       (4

Balance, December 31

   $ 205     $ 172  

 

(1)

Tampa Electric produces ash and other by-products, collectively known as CCRs, at its Big Bend and Polk power stations. The 2018 additions to ARO are to achieve compliance with the EPA’s CCR rule, which contains design and operating standards for CCR management units. Tampa Electric submitted a petition to the FPSC in December 2018 for recovery of costs associated with the ongoing project and the petition is currently under review.

 

EMERA 2018 ANNUAL REPORT

137


NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

 

26. COMMITMENTS AND CONTINGENCIES

A. COMMITMENTS

As at December 31, 2018, contractual commitments (excluding pensions and other post-retirement obligations, convertible debentures, long-term debt and AROs) for each of the next five years and in aggregate thereafter consisted of the following:

 

millions of Canadian dollars   

2019

 

    

2020

 

    

2021

 

    

2022

 

    

2023

 

    

Thereafter

 

    

Total

 

 

 

Purchased power (1)

   $         204      $         203      $         209      $         208      $         209      $       2,194      $       3,227  

Transportation (2) (3)

     569        347        255        215        170        1,492        3,048  

Fuel and gas supply

     642        237        49        7        3               938  

Capital projects (4)

     524        147        45        11        3        8        738  

Long-term service agreements (5) (6)

     110        67        42        30        33        246        528  

Equity investment commitments (7)

            190                                    190  

Leases and other (8)

     18        15        10        9        7        75        134  

Demand side management

     44        1                                    45  
     $ 2,111      $ 1,207      $ 610      $ 480      $ 425      $ 4,015      $ 8,848  

 

(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.

(3)

Includes $82 million related to NEGG transportation capacity ($5 million in 2019; $5 million in 2020; $5 million in 2021; $4 million in 2022; $4 million in 2023 and $59 million thereafter). On completion of the sale of the NEGG facilities, the remaining future contractual obligations will be transferred to the buyer. Refer to note 17 for additional information.

(4)

Includes $439 million of commitments related to Tampa Electric’s solar and Big Bend Power Station modernization projects.

(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)

Includes $248 million related to various long-term service agreements NEGG has entered into for maintenance of certain generating equipment ($46 million in 2019; $9 million in 2020; $24 million in 2021; $16 million in 2022; $16 million in 2023 and $137 million thereafter). On completion of the sale of the NEGG facilities, the remaining future contractual obligations will be transferred to the buyer. Refer to note 17 for additional information.

(7)

Emera has a commitment to make equity contributions to the Labrador Island Link Limited Partnership.

(8)

Operating lease agreements for office space, land, plant fixtures and equipment, telecommunications services, rail cars and vehicles.

NSPI has a contractual obligation to pay NSPML for the use of the Maritime Link over approximately 37 years. In January 2018, NSPI started paying the UARB approved interim assessment payments and as of December 31, 2018, $96 million has been paid to NSPML. The UARB approved payment for 2019 is $111 million and is subject to a $10 million holdback. Refer to note 14 for additional information. After 2019, the timing of and amounts payable to NSPML will be subject to regulatory filings with the UARB, with expected filings in 2019 and 2020.

B. LEGAL PROCEEDINGS

Emera Florida and New Mexico

TECO Guatemala Holdings (“TGH”)

In 2013, the International Centre for the Settlement of Investment Disputes (“ICSID”) Tribunal hearing the arbitration claim of TGH, a wholly owned subsidiary of TECO Energy, against the Republic of Guatemala (“Guatemala”) under the Dominican Republic Central America – United States Free Trade Agreement, issued an award in the case (“the Award”). 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 two per cent. This award was upheld in subsequent annulment proceedings in 2016 and, in addition, TGH’s application for partial annulment of the award was granted, and Guatemala was ordered to pay certain costs relating to the annulment proceedings. As a result, TGH had the right to resubmit its arbitration claim against Guatemala to seek additional damages (in addition to the previously awarded $21 million USD), as well as additional interest on the $21 million USD, and its full costs relating to the original arbitration and the new arbitration proceeding.

On September 23, 2016, TGH filed a request for resubmission to arbitration. A new tribunal was constituted and the matter has been fully briefed. A hearing is scheduled for March 2019 and a decision is expected from the tribunal in 2020. In addition, TGH has sued Guatemala in Washington, D.C. court to enforce the $21 million USD owing. Guatemala’s motion to dismiss the enforcement action was denied. The parties are in the process of filing motions on the matter. Results to date do not reflect any benefit.

 

EMERA 2018 ANNUAL REPORT

138


NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

 

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, 2018, TEC has estimated its financial liability to be $38 million ($28 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

From 2011 to 2016, four separate complaints were filed with the FERC to challenge the base ROE under the ISO-New England (“ISO-NE”) Open Access Transmission Tariff (“OATT”).

 

   

Complaint I, filed by a group including the Attorney General of Massachusetts, New England utilities commissions, state public advocates and end users, was remanded to the FERC by the US Court of Appeals in 2017 for further proceedings. No reserve has been made with respect to Complaint I due to uncertainty of the outcome.

 

   

Complaints II and III (the “ENE” and “MA AG II” cases), brought by a group of consumer advocates and by a group of state commissions, state public advocates and end users respectively, have been joined together and are presently pending before the FERC. Emera Maine has recorded a reserve of approximately $4 million USD for these cases. These reserves have been recorded as “Regulatory liabilities” on the Consolidated Balance Sheets and as a reduction to “Operating revenues – regulated electric” on the Consolidated Statements of Income. The reserve was calculated based on Emera Maine’s best estimate of the probable outcome.

 

   

Complaint IV was filed by the Eastern Massachusetts Consumer Owned Systems (“EMCOS”). On March 27, 2018, a FERC Administrative Law Judge issued an Initial Decision concluding that the currently-filed base ROE of 10.57 per cent, which with incentive adders may reach a maximum ROE of 11.74 per cent, is not unjust and unreasonable. This decision was appealed to the FERC. No reserve has been made in relation to Complaint IV due to the uncertainty of the final outcome.

On October 16, 2018, the FERC issued an order that addressed all four complaint proceedings. The FERC order proposed a new methodology to set ROEs. Based on the new methodology, the FERC’s preliminary finding was a 10.41 per cent base ROE for the ISO-NE OATT. The FERC has permitted parties to comment on the new methodology and its application to the four pending complaint proceedings. No new or additional reserves have been made with respect to all four pending complaints due to uncertainty.

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 2018 ANNUAL REPORT

139


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 12 and note 13.

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.

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 uses foreign currency derivative instruments to hedge specific transactions. 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. 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 will be financed through internally generated cash flows, select asset sales, short-term credit facilities, and ongoing access to capital markets. Cash flows generated from the sale of select assets are dependent on the market for the assets, acceptable pricing and the timing of the close of any sales. The Company reasonably expects liquidity sources to exceed capital needs.

Emera’s access to capital and cost of borrowing is subject to a number of risk factors including financial market conditions 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. Emera is subject to risk with changes in interest rates that could have an adverse effect on the cost of financing. Inability to access to cost-effective capital could have a material impact on Emera’s ability to fund its growth plan.

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, and liquidity. 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. Emera manages this risk 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, preferred share units and deferred share units.

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 into interest rate hedging contracts to limit its exposure to fluctuations in floating interest rate debt.

 

EMERA 2018 ANNUAL REPORT

140


NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

 

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

A large portion of the Company’s fuel supply comes from international suppliers and is subject to commodity price risk. The Company manages this risk through established processes and practices to identify, monitor, report and mitigate these risks. Fuel contracts 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 through the use of financial hedging instruments and physical contracts and through contractual protection with counterparties, where applicable. In addition, the adoption and implementation of fuel adjustment mechanisms in its rate-regulated subsidiaries has further helped manage this risk, as the regulatory framework for the Company’s rate-regulated subsidiaries permits the recovery of prudently incurred fuel costs.

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 several significant guarantees and letters of credit on behalf of third parties outstanding. The following guarantees and letters of credit are not included within the Consolidated Balance Sheets as at December 31, 2018:

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.

The Company has standby letters of credit and surety bonds in the amount of $67 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 Reinsurance Limited has issued a standby letter of credit to secure its obligations under reinsurance agreements. The letter of credit expires in February 2019 and is renewed annually. The amount committed as of December 31, 2018 was $6 million USD.

Emera Inc., on behalf of NSPI, has a standby letter of credit to secure obligations under a supplementary retirement plan. The letter of credit expires in June 2019 and is renewed annually. The amount committed as at December 31, 2018 was $49 million.

Collaborative Arrangements

For the years ended December 31, 2018 and 2017, 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 2018, NSPI recognized $19 million net expense (2017 – $18 million) in “Regulated fuel for generation and purchased power” and $2 million (2017 – $3 million) in OM&G.

 

EMERA 2018 ANNUAL REPORT

141


NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

 

27. CUMULATIVE PREFERRED STOCK

Authorized:

Unlimited number of First Preferred shares, issuable in series.

Unlimited number of Second Preferred shares, issuable in series.

 

              December 31, 2018        December 31, 2017  
      
Annual Dividend
Per Share
 
 
    
Redemption
Price per share
 
 
    
Issued and
Outstanding
 
 
    

Net

Proceeds

 

 

    
Issued and
Outstanding
 
 
    
Net
  Proceeds
 
 

Series A

     $        0.6388        $        25.00        3,864,636        $           95        3,864,636      $ 95  

Series B

     Floating        $        25.00        2,135,364        $           52        2,135,364      $ 52  

Series C

     $        1.1802        $        25.00        10,000,000        $         245        10,000,000      $ 245  

Series E

     $        1.1250        $        26.00        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             $  

Total

                       41,000,000        $      1,004        29,000,000      $ 709  

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

     4.400        0.6388        1.84        August 15, 2020        25.00        Series B

Series C (5)

     4.100        1.1802        2.65        August 15, 2023        25.00        Series D  

Series F

     4.250        1.0625        2.63        February 15, 2020        25.00        Series G  

Minimum rate reset (3) (4)

                 

Series B

     2.393        Floating        1.84        August 15, 2020        25.00        Series A  

Series H

     4.900        1.2250        4.90        August 15, 2023        25.00        Series I  

Perpetual fixed rate

                 

Series E (6)

     4.500        1.1250                          26.00           

 

(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, 2018, 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 C was reset from $1.0250 to $1.1802 for the five-year period from and including August 15, 2018.

(6)

First Preferred Shares, Series E are redeemable at $26.00 to August 15, 2019, 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.

 

EMERA 2018 ANNUAL REPORT

142


NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

 

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.

28. NON-CONTROLLING INTEREST IN SUBSIDIARIES

Non-controlling interest in subsidiaries consisted of the following:

 

As at

millions of Canadian dollars

   December 31
2018
    December 31
2017
 

Domlec

   $ 22     $ 21  

Preferred shares of GBPC

     19       19  

ICDU (1)

           52  
     $ 41     $ 92  
(1)

On January 15, 2018, Emera completed the acquisition of the minority shareholder common shares for total consideration of $35 million USD. This acquisition increases Emera’s indirect ownership interest to 100 per cent.

PREFERRED SHARES OF GBPC:

Authorized:

20,000 non-voting cumulative redeemable variable perpetual preferred shares.

 

              2018              2017  
Issued and outstanding:    number of
shares
     millions of
dollars
     number of
shares
     millions of
dollars
 

Outstanding as at December 31

     20,000      $ 19        20,000      $ 19  

GBPC NON–VOTING CUMULATIVE VARIABLE PERPETUAL PREFERRED STOCK:

The Preferred Stock is redeemable by GBPC, in whole at any time or in part from time to time, at $1,000 Bahamian per share plus accrued and unpaid dividends.

The Preferred Stock is entitled to a 7.25 per cent per annum fixed cumulative preferential dividend for years 2013 through 2016,

8.50 per cent per annum fixed cumulative preferential dividend for years 2017 through 2019 and 10.00 per cent per annum fixed cumulative preferential dividend after 2020, as and when declared by the Board of Directors, accruing from the date of issue.

The Preferred Shares rank behind all of GBPC’s current and future secured and unsecured debt with any of GBPC’s future preferred stock and ahead of all of GBPC’s current and future common stock.

 

EMERA 2018 ANNUAL REPORT

143


NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

 

29. SUPPLEMENTARY INFORMATION TO CONSOLIDATED STATEMENTS OF CASH FLOWS

 

For the

     Year ended December 31  

millions of Canadian dollars

     2018       2017  

Changes in non-cash working capital:

    

Inventory

   $ (44   $ 31  

Receivables and other current assets

     (144     (154

Accounts payable

     59       3  

Other current liabilities

     13       16  

Total non-cash working capital

   $ (116   $ (104

Supplemental disclosure of cash paid:

                

Interest

   $         653     $         689  

Income taxes

   $ 33     $ 63  

Supplemental disclosure of non-cash activities:

                

Common share dividends reinvested

   $ 181     $ 166  

Change in accrued capital expenditures

   $ (50   $ 13  

Issuance of depository receipts

   $ 22     $  

30. 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 to which employees make cash contributions of a minimum of $25 to a maximum of $8,000 per year for the purpose of purchasing common shares of Emera. The Company also contributes to the plan a percentage of the employees’ contributions. If an employee contributes any amount up to $3,000 to that employee’s plan account, the Company will contribute 20 per cent of that amount. When an employee contributes any amount over $3,000, up to the $8,000 maximum, the Company will contribute 10 per cent of that amount.

The plan allows the reinvestment of dividends. The maximum aggregate number of Emera common shares reserved for issuance under this plan is 4 million common shares. As at December 31, 2018, Emera is in compliance with this requirement.

Compensation cost for shares issued by Emera for the year ended December 31, 2018 under the Employee Common Share Purchase Plan was $1 million (2017 – $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 for the purpose of purchasing 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.

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 ten 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, 2018, 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 ten 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.

 

EMERA 2018 ANNUAL REPORT

144


NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

 

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:

 

              2018              2017       

Weighted average fair value per option

   $          1.70      $          2.37    

Expected term (1)

        6 years           5 years    

Risk-free interest rate (2)

        2.13%           1.22%    

Expected dividend yield (3)

        5.69%           4.60%    

Expected volatility (4)

              13.71%                 14.41%      

 

(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.

The following table summarizes stock option information for 2018:    

 

      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, 2017

     3,643,575     $          39.42        1,739,650     $          2.52    

Granted

     627,600          39.93        627,600          1.70    

Exercised

     (23,800        24.98        N/A          N/A    

Vested

     N/A          N/A        (666,125        2.51    

Forfeited

     (11,700        45.10        (11,700        2.54    

Expired

     (10,100              39.93        (10,100              1.70      

Options outstanding December 31, 2018

     4,225,575     $          39.56        1,679,325     $          2.22      

Options exercisable December 31, 2018 (2) (3)

     2,546,250     $          37.15                                
(1)

As at December 31, 2018, there was $5 million of unrecognized compensation related to stock options not yet vested which is expected to be recognized over a weighted average period of approximately 2.2 years (2017 – $3 million, 2.5 years).

(2)

As at December 31, 2018, the weighted average remaining term of vested options was 5.1 years with an aggregate intrinsic value of $18 million (2017 – 5.4 years, $22 million).

(3)

As at December 31, 2018, the fair value of options that vested in the year was $2 million (2017 – $2 million).

Compensation cost recognized for stock options for the year ended December 31, 2018 was $1 million (2017 – $2 million), which is included in “Operating, maintenance and general” on the Consolidated Statements of Income.

As at December 31, 2018, cash received from option exercises was $1 million (2017 – $3 million). The total intrinsic value of options exercised for the year ended December 31, 2018 was $1 million (2017 – $2 million). The range of exercise prices for the options outstanding as at December 31, 2018 was $21.99 to $46.19 (2017 – $21.58 to $46.19).

 

EMERA 2018 ANNUAL REPORT

145


NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

 

SHARE UNIT PLANS

The Company has DSU and PSU plans and the liabilities are marked-to-market at the end of each period based on the 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, also referred to as DRIP. 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 the average of Emera’s stock closing price during the ten trading days ending on the tenth trading day prior to the payment date.

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.

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 to achieve certain corporate objectives.

A summary of the activity related to employee and director DSUs for the year ended December 31, 2018 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, 2017

     751,600     $ 28.44        472,485     $ 35.33  

Granted including DRIP

     90,549       38.72        101,676       43.93  

Exercised

     (5,040     30.15        (10,640     25.31  

Outstanding and exercisable as at December 31, 2018

     837,109     $ 29.54        563,521     $ 37.07  

Compensation cost recognized for employee and director DSU for the year ended December 31, 2018 was $2 million (2017 – $7 million). Tax benefits related to this compensation cost for share units realized for the year ended December 31, 2018 were $1 million (2017 – $2 million). The aggregate intrinsic value of the outstanding shares for the year ended December 31, 2018 was $37 million (2017 – $35 million).

 

EMERA 2018 ANNUAL REPORT

146


NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

 

Performance Share Unit Plan

Under the PSU plan, 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 a given calculation date. Dividend equivalents are awarded and paid in the form of additional PSUs, also referred to as DRIP. 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 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 will be pro-rated in the case of termination, disability or death.

A summary of the activity related to employee PSUs for the year ended December 31, 2018 is presented in the following table:

 

      Employee
PSU
    Weighted
Average Grant
Date Fair Value
     Aggregate
intrinsic value
 

Outstanding as at December 31, 2017

     829,998     $ 43.41      $ 41.1  

Granted including DRIP

     486,181       47.84     

Exercised

     (176,805     38.85     

Forfeited

     (12,260     44.88           

Outstanding as at December 31, 2018

     1,127,114     $ 46.02      $ 56.9  

Compensation cost recognized for the PSU plan for the year ended December 31, 2018 was $14 million (2017 – $14 million). Tax benefits related to this compensation cost for share units realized for the year ended December 31, 2018 were $4 million (2017 – $4 million).

31. 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. In Q2 2014, when the critical milestones were achieved, Nalcor Energy was deemed the primary beneficiary of the asset for financial reporting purposes as they have 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 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.

 

EMERA 2018 ANNUAL REPORT

147


NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

 

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, 2018

   

December 31, 2017

 
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)

  $         545     $         51     $         510     $         67  

32. 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.

33. SUBSEQUENT EVENTS

These financial statements and notes reflect the Company’s evaluation of events occurring subsequent to the balance sheet date through February 15, 2019, the date the financial statements were issued.

34. 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.

 

EMERA 2018 ANNUAL REPORT

148


 

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, 2018

                                                

Operating revenues

   $     $     $ 4,432     $ 2,146     $ (54   $ 6,524  

Operating expenses

     45             3,468       1,665       (52     5,126  

Income (loss) from equity investments and subsidiaries

     801             3       150       (800     154  

Other income (expenses), net

     22             20       (27     (38     (23

Interest expense, net (1)

     79       (40     456       218             713  

Income (loss) before provision for income taxes

     699       40       531       386       (840     816  

Income tax expense (recovery)

     (47     9       64       43             69  

Net income (loss)

     746       31       467       343       (840     747  

Non-controlling interest in subsidiaries

                       (1     2       1  

Preferred stock dividends

     36             38       4       (42     36  

Net income (loss) attributable to common shareholders

   $ 710     $ 31     $ 429     $ 340     $ (800   $ 710  

Comprehensive income (loss) of Emera Incorporated

   $     1,249     $     56     $ 973     $ 439     $     (1,468   $ 1,249  
                                                  

For the year ended December 31, 2017

                                                

Operating revenues

   $     $     $     4,274     $     2,009     $ (57   $     6,226  

Operating expenses

     41             3,241       1,583       (57     4,808  

Income (loss) from equity investments and subsidiaries

     337             1       122       (336     124  

Other income (expenses), net

     38             15       (46     (32     (25

Interest expense, net (1)

     84       (40     451       203             698  

Income (loss) before provision for income taxes

     250       40       598       299       (368     819  

Income tax expense (recovery)

     (44     17       511       36             520  

Net income (loss)

     294       23       87       263       (368     299  

Non-controlling interest in subsidiaries

                       1       4       5  

Preferred stock dividends

     28             29       13       (42     28  

Net income (loss) attributable to common shareholders

   $ 266     $ 23     $ 58     $ 249     $ (330   $ 266  

Comprehensive income (loss) of Emera Incorporated

   $ (6   $ 3     $ (291   $ 265     $ 23     $ (6

 

(1)

Interest expense is net of interest revenue.

 

EMERA 2018 ANNUAL REPORT

149


 

Emera Incorporated

CONDENSED CONSOLIDATED BALANCE SHEETS

 

millions of Canadian dollars

 

  

Parent

 

    

Subsidiary
Issuer

 

    

Guarantor
Subsidiaries

 

    

Non-guarantor
Subsidiaries

 

    

Eliminations

 

   

Consolidated

 

 

 

As at December 31, 2018

                                                    

Assets

                

Current assets

   $ 146      $ 67      $ 1,767      $ 1,096      $ (244   $ 2,832  

Property, plant and equipment

     24               13,745        4,946        (3     18,712  

Other assets

                

Regulatory assets

                   645        759              1,404  

Goodwill

                   6,208        105              6,313  

Other long-term assets

     11,457        4,660        971        3,200        (17,235     3,053  

Total other assets

     11,457        4,660        7,824        4,064        (17,235     10,770  

Total assets

   $ 11,627      $ 4,727      $ 23,336      $ 10,106      $ (17,482   $ 32,314  

Liabilities and Equity

                

Current liabilities

   $ 368      $ 695      $ 2,829      $ 926      $ (265   $ 4,553  

Long-term liabilities

                

Long-term debt

     2,906        3,709        10,243        4,428        (6,994     14,292  

Deferred income taxes

            3        668        643        6       1,320  

Regulatory liabilities

                   2,118        241              2,359  

Other long-term liabilities

     36               874        543        (21     1,432  

Total long-term liabilities

     2,942        3,712        13,903        5,855        (7,009     19,403  

Total Emera Incorporated equity

     8,317        320        6,604        3,303        (10,227     8,317  

Non-controlling interest in subsidiaries

                          22        19       41  

Total equity

     8,317        320        6,604        3,325        (10,208     8,358  

Total liabilities and equity

   $ 11,627      $ 4,727      $ 23,336      $ 10,106      $ (17,482   $ 32,314  

As at December 31, 2017

                                                    

Assets

                

Current assets

   $ 358      $ 30      $ 1,420      $ 891      $ (173   $ 2,526  

Property, plant and equipment

     17               12,258        4,720              16,995  

Other assets

                

Regulatory assets

                   587        686              1,273  

Goodwill

                   5,709        96              5,805  

Other long-term assets

     9,761        4,285        156        3,094        (15,089     2,207  

Total other assets

     9,761        4,285        6,452        3,876        (15,089     9,285  

Total assets

   $ 10,136      $ 4,315      $ 20,130      $ 9,487      $ (15,262   $ 28,806  

Liabilities and Equity

                

Current liabilities

   $ 129      $ 12      $ 3,293      $ 714      $ (202   $ 3,946  

Long-term liabilities

                

Long-term debt

     2,861        4,034        8,468        4,262        (6,485     13,140  

Deferred income taxes

            4        447        565        7       1,023  

Regulatory liabilities

                   1,888        354              2,242  

Other long-term liabilities

     34               691        550        (24     1,251  

Total long-term liabilities

     2,895        4,038        11,494        5,731        (6,502     17,656  

Total Emera Incorporated equity

     7,112        265        5,343        2,970        (8,578     7,112  

Non-controlling interest in subsidiaries

                          72        20       92  

Total equity

     7,112        265        5,343        3,042        (8,558     7,204  

Total liabilities and equity

   $   10,136      $     4,315      $   20,130      $     9,487      $   (15,262   $   28,806  

 

EMERA 2018 ANNUAL REPORT

150


 

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, 2018

                                                 

Net cash provided by (used in) operating activities

   $ 191     $ 35      $ 1,266     $ 465     $ (267   $ 1,690  

Investing activities

             

Additions to property, plant and equipment

     (9            (1,687     (466           (2,162

Net purchase of investments subject to significant influence

                  (16     (33           (49

Other investing activities

     (489            3       (65     572       21  

Net cash provided by (used in) investing activities

             (498                    (1,700             (564             572               (2,190

Financing activities

             

Change in short-term debt, net

                  (162                 (162

Proceeds from long-term debt

                  1,174       75       (194     1,055  

Retirement of long-term debt

                  (716     (41           (757

Net borrowings (repayments) under committed credit facilities

     136              (103     178       110       321  

Issuance of common and preferred stock

     301              319       127       (446     301  

Dividends paid

     (382            (37     (311     348       (382

Other financing activities

                        91       (123     (32

Net cash provided by (used in) financing activities

     55              475       119       (305     344  

Effect of exchange rate changes on cash, cash equivalents and restricted cash

     (4     2        9       18             25  

Net increase (decrease) in cash, cash equivalents and restricted cash

     (256     37        50       38             (131

Cash, cash equivalents and restricted cash, beginning of year

     276       21        54       152             503  

Cash, cash equivalents and restricted cash, end of year

   $ 20     $ 58      $ 104     $ 190     $     $ 372  

 

EMERA 2018 ANNUAL REPORT

151


 

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, 2017                                           

Net cash provided by (used in) operating activities

   $ 195     $ 22     $ 658     $ 1,080     $ (762   $ 1,193  

Investing activities

            

Additions to property, plant and equipment

     (5           (1,031     (480     (13     (1,529

Net purchase of investments subject to significant influence

                       (213           (213

Other investing activities

     (742     (26     (5     1,852       (1,098     (19

Net cash provided by (used in) investing activities

     (747     (26     (1,036     1,159       (1,111     (1,761

Financing activities

            

Change in short-term debt, net

                 365       (13           352  

Proceeds from long-term debt

                 147       (31     13       129  

Retirement of long-term debt

                 (413     (55     15       (453

Net borrowings (repayments) under committed credit facilities

     (30           59       192       9       230  

Issuance of common and preferred stock

     682             134       (2,032     1,898       682  

Dividends paid

     (315           (29     (285     314       (315

Other financing activities

     290             96       (42     (376     (32

Net cash provided by (used in) financing activities

     627             359       (2,266     1,873       593  

Effect of exchange rate changes on cash, cash equivalents and restricted cash

     1       (3     1       (12           (13

Net increase (decrease) in cash, cash equivalents and restricted cash

     76       (7     (18     (39           12  

Cash, cash equivalents and restricted cash, beginning of year

     200       28       72       191             491  

Cash, cash equivalents and restricted cash, end of year

   $     276     $         21     $ 54     $ 152     $     $ 503  

 

EMERA 2018 ANNUAL REPORT

152


 

EMERA LEADERSHIP & BOARD

 

EMERA LEADERSHIP

(as of March 30, 2019)

 

BOARD OF DIRECTORS

(as of March 30, 2019)

 

Scott Balfour

President and

Chief Executive Officer,

Emera Inc.

Rob Bennett

President and Chief

Executive Officer,

Emera Technologies Inc.

Greg Blunden

Chief Financial Officer,

Emera Inc.

Robert Hanf

Executive Vice President,

Stakeholder Relations

and Regulatory Affairs,

Emera Inc.

Mike Herrin

President and Chief

Operating Officer,

Emera Maine

Karen Hutt

President and

Chief Executive Officer,

Nova Scotia Power

Rick Janega

Chief Operating Officer,

Electric Utilities, Canada,

US Northeast and Caribbean,

Emera Inc.

Sarah MacDonald

Executive Vice President,

Corporate Safety

and Environment,

Emera Inc.

President,

TECO Services Inc.

Bruce Marchand

Chief Legal and Compliance

Officer,

Emera Inc.

Dan Muldoon

Executive Vice President,

Project Development

and Operations Support,

Emera Inc.

Wayne O’Connor

Executive Vice President,

Business Development

& Strategy,

Emera Inc.

Michael Roberts

Chief Human Resources

Officer,

Emera Inc.

Ryan Shell

President,

New Mexico Gas Company

Judy Steele

President and

Chief Operating Officer,

Emera Energy

T.J. Szelistowski

President,

Peoples Gas

Nancy Tower

President and

Chief Executive Officer,

Tampa Electric Company

Jackie Sheppard

Chair, Emera Inc.

Former Executive

Vice President,

Corporate & Legal Affairs,

Talisman Energy Inc.,

Calgary, Alberta

Scott Balfour

President and CEO,

Emera Inc.,

Halifax, Nova Scotia

James Bertram

Chair of the Board,

Keyera Corporation,

Calgary, Alberta

Sylvia Chrominska

Former Group Head,

Global Human Resources

and Communications,

The Bank of Nova Scotia,

Toronto, Ontario

Henry Demone

Chairman,

High Liner Foods,

Lunenburg, Nova Scotia

Allan Edgeworth

Former President,

ALE Energy Inc.,

Calgary, Alberta

James Eisenhauer, FCPA, FCA

President,

AGL Group Holdings Ltd.,

Lunenburg, Nova Scotia

Kent Harvey

Former Senior Vice President

and Chief Financial Officer,

PG&E Corporation,

New York, New York

Lynn Loewen, FCPA, FCA

President,

Minogue Medical Inc.,

Westmount, Quebec

Donald Pether

Former Chair of the Board

and Chief Executive Officer,

ArcelorMittal Dofasco Inc.,

Dundas, Ontario

John Ramil

Former President and

Chief Executive Officer,

TECO Energy, Inc.,

Tampa, Florida

Andrea Rosen

Former Vice Chair,

TD Bank Financial Group,

and President,

TD Canada Trust,

Toronto, Ontario

Richard Sergel

Former President and

Chief Executive Officer,

North American Electric

Reliability Corporation

(NERC),

Boston, Massachusetts

Jochen Tilk

Former Executive Chair,

Nutrien Ltd.,

Saskatoon, Saskatchewan

 

 

EMERA 2018 ANNUAL REPORT

153


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

Information regarding Company news and initiatives, including our 2018 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

Vice President, Investor Relations

and Treasurer

Ken McOnie

T: 902.428.6945

E: ken.mconie@emera.com

Manager, Investor Relations

Erin Power

T: 902.428.6760

E: erin.power@emera.com

ANNUAL MEETING

The Annual Meeting is scheduled to be held May 15, 2019 at 2:00 p.m. (Atlantic Time) at the Halifax Convention Centre, 1650 Argyle Street, Halifax, Nova Scotia.

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: 234,124,717 (as of December 31, 2018)

DIVIDENDS PAID IN 2018

Emera Inc. paid Common Share dividends of $0.5650 per Common Share in Q1, Q2 and Q3 and $0.5875 in Q4, for an effective annual Common Share dividend rate of $2.2825 per Common Share.

DIVIDEND PAYMENTS IN 2019

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 $0.5875, a Series A First Preferred Share dividend of $0.1597, a Series B First Preferred Share dividend of $0.2206, 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 $0.265625 and a Series H First Preferred Share dividend of $0.30625 was declared and paid on February 15, 2019.

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. 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

Shareholders may have dividends deposited directly into accounts held at financial institutions that are members of the Canadian Payments Association. To arrange this service, please contact AST Trust Company (Canada).

QUARTERLY EARNINGS

Quarterly earnings are expected to be announced May, August and November 2019. Year-end results for 2018 were released in February 2019.

 

 

 

EMERA 2018 ANNUAL REPORT

154


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LOGO

EX-99.3 4 d732548dex993.htm EX-99.3 EX-99.3

Exhibit 99.3

 

LOGO

   LOGO

Form of Proxy - Emera Inc.

Annual Shareholders Meeting of May 15, 2019

 

 

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 attend, 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 2:00 p.m. Atlantic Time on Wednesday, May 15, 2019, in the Halifax Convention Centre, Argyle Suite, Level 2, 1650 Argyle Street, Halifax, Nova Scotia, Canada (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, and 4. Please use a dark black pencil or pen.

 

    1.        

   Election of Directors    FOR    WITHHOLD       FOR    WITHHOLD
  

01.  Scott C. Balfour

        

07.  Donald A. Pether

     
  

02.  James V. Bertram

        

08.  John B. Ramil

     
  

03.  Sylvia D. Chrominska

        

09.  Andrea S. Rosen

     
  

04.  Henry E. Demone

        

10.  Richard P. Sergel

     
  

05.  Kent M. Harvey

        

11.  M. Jacqueline Sheppard

     
  

06.  B. Lynn Loewen

        

12.  Jochen E. Tilk

     
    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    FOR    AGAINST
  

Consider and approve, on an advisory basis, a resolution on Emera’s approach to executive compensation as disclosed in the Management Information Circular

     

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.

 

NON-RESIDENT VOTING CONSTRAINT    YES    NO
Are the shares represented by this Proxy held, beneficially owned or controlled, directly or indirectly, by a resident of Canada?      

 

 

   

 

Signature(s)

 

            

 

Date

Please sign exactly as your name(s) appear on this proxy. Please see reverse for instructions. All proxies must be received by 2:00 p.m. Atlantic Time, Monday, May 13, 2019.

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

 

A. Shareholder

320 Bay St., 3rd Floor

Toronto, ON M5T 2A4

Line 6

Line 7

   LOGO


Form of Proxy - Emera Inc.

Annual Shareholders Meeting of May 15, 2019

 

 

Notes to Proxy

 

1.

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, and if the corporation has a corporate seal, its corporate seal should be affixed.

 

2.

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.

 

3.

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.

 

4.

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.

 

5.

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.

 

     

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 2:00 p.m. Atlantic Time, Monday, May 13, 2019.

EX-99.4 5 d732548dex994.htm EX-99.4 EX-99.4

Exhibit 99.4

 

LOGO   LOGO

Voting Instruction Form (“VIF”) - Emera Inc.

Annual Shareholders Meeting of May 15, 2019

                                                                                                                                                                    

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 attend the meeting and vote or to appoint someone to attend and vote on your behalf, print that name here]

as proxy of the undersigned, to attend, 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 2:00 p.m. Atlantic Time on Wednesday, May 15, 2019, in the Halifax Convention Centre, 1650 Argyle Street, Halifax, Nova Scotia, Canada (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, and 4. Please use a dark black pencil or pen.

 

    1.

  

Election of Directors

       FOR            WITHHOLD               FOR            WITHHOLD    
  

01.  Scott C. Balfour

        

07.  Donald A. Pether

     
  

02.  James V. Bertram

        

08.  John B. Ramil

     
  

03.  Sylvia D. Chrominska

        

09.  Andrea S. Rosen

     
  

04.  Henry E. Demone

        

10.  Richard P. Sergel

     
  

05.  Kent M. Harvey

        

11.  M. Jacqueline Sheppard

     
  

06.  B. Lynn Loewen

        

12.  Jochen E. Tilk

     
    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    FOR    AGAINST
  

Consider and approve, on an advisory basis, a resolution on Emera’s approach to executive compensation as disclosed in the Management Information Circular

     

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.

 

NON-RESIDENT VOTING CONSTRAINT   YES   NO
Are the shares represented by this Voting Instruction Form held, beneficially owned or controlled, directly or indirectly, by a resident of Canada?    

 

 

                     

 

                  
Signature(s)      Date  

Please sign exactly as your name(s) appear on this VIF. Please see reverse for instructions. All VIFs must be received by 2:00 p.m. Atlantic Time, Monday, May 13, 2019.

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

 

A. Shareholder

320 Bay St., 3rd Floor

Toronto, ON    M5T 2A4

Line 6

Line 7

   LOGO


Voting Instruction Form (“VIF”) - Emera Inc.

Annual Shareholders Meeting of May 15, 2019

                                                                                                                                                                    

 

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 attend the Meeting and vote in person, your securities can be voted only by management, as appointee of the registered holder, in accordance with your instructions.

2.

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.

3.

If you want to attend the Meeting and vote in person, please write your name in the place provided for that purpose in this form. You can also write the name of someone else whom you wish to attend the Meeting and vote on your behalf. 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.

4.

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.

5.

If this VIF is not dated it will be deemed to bear the date on which it is mailed by management to you.

6.

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.

7.

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 thereof.

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.

 

     

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 2:00 p.m. Atlantic Time, Monday, May 13, 2019.

EX-99.5 6 d732548dex995.htm EX-99.5 EX-99.5

Exhibit 99.5

 

LOGO

ANNUAL SHAREHOLDERS MEETING OF

EMERA INCORPORATED

NOTICE TO SHAREHOLDERS

REGARDING ACCESS TO EMERA’S MANAGEMENT INFORMATION CIRCULAR

and ANNUAL REPORT

 

 

  MEETING DATE and LOCATION

 

  Date:            Wednesday, May 15, 2019

 

  Time:           2:00 p.m. Atlantic Time

 

  Place:           Halifax Convention Centre, Argyle Suite, Level 2

                        1650 Argyle Street, Halifax, Nova Scotia, Canada

 

 

   LOGO

WHY AM I RECEIVING THIS NOTICE?

 

   LOGO

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 2018 Annual Report (together, the “Meeting Materials”), electronically, instead of mailing paper copies. This notice provides you 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.

 

   LOGO

WHERE CAN I ACCESS THE MEETING MATERIALS ON-LINE?

 

   LOGO

The Meeting Materials can be viewed online at www.meetingdocuments.com/astca/ema as of Monday, April 8, 2019 for a period of one year following the Meeting, or at www.SEDAR.com.

 

   LOGO

HOW CAN I OBTAIN A PAPER COPY OF THE MEETING MATERIALS?

 

   LOGO

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 3 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 2:00 p.m. Atlantic Time on Thursday, May 2, 2019. To receive the Meeting Materials prior to the Meeting you should make your request before 2:00 p.m. Atlantic Time on Monday, May 6, 2019.

Requests for paper copies of the Meeting Materials can be made until  one year following the Meeting.


LOGO

 

    Q

WHAT MATTERS ARE BEING RECEIVED OR VOTED ON AT THE MEETING?

 

    A

Shareholders are being asked to vote on the following items of business:

 

 

MEETING BUSINESS ITEM

 

  

 

INFORMATION CIRCULAR REFERENCE

 

 

  1.  Election of Directors – elect directors of the Company for the ensuing year.

 

  

 

See page 5 of the Information Circular for more information

 

  2.  Appointment of Auditors – appoint Ernst & Young LLP as auditors for the ensuing year.

 

  

 

See page 6 of the Information Circular for more information

  3.  Authorize Remuneration of Auditors – authorize the directors to fix the remuneration of the Auditors.

  

 

See page 6 of the Information Circular for more information

 

  4.  Say on Pay – an advisory resolution on the Company’s approach to executive compensation.

 

  

 

See page 6 of the Information Circular for more information

All Shareholders are reminded to review the Information Circular and 2018 Annual Report before voting.

 

    Q

HOW DO I VOTE MY SHARES?

 

    A

You may vote by Internet, telephone, posted mail, delivered mail, e-mail or fax. Details of the methods of voting can be found on your accompanying proxy form. You will need your control number contained in the accompanying proxy form in order to vote by telephone or by Internet.

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 2:00 p.m. Atlantic Time on Monday, May 13, 2019 or, if the Meeting is adjourned or postponed, by 2:00 p.m. Atlantic Time two business days before the reconvened meeting date (or proxy deadline). Emera reserves the right to accept late proxies and to waive the proxy deadline, with or without notice, but is under no obligation to accept or reject any particular late proxy.

 

    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 or fulfillment@astfinancial.com

EX-99.6 7 d732548dex996.htm EX-99.6 EX-99.6

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:    Wednesday, May 15, 2019
  Time:    2:00 p.m. Atlantic Time
  Place:   

Halifax Convention Centre, Argyle Suite, Level 2,

1650 Argyle Street, Halifax, Nova Scotia, Canada

 

 

   LOGO

WHY AM I RECEIVING THIS NOTICE?

 

   LOGO

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 2018 Annual Report (together, the “Meeting Materials”), electronically, instead of mailing paper copies. This notice provides you information on how to view the Meeting Materials online and / or request paper copies. Accompanying this notice is the voting instruction form that you will need to vote.

 

   LOGO

WHERE CAN I ACCESS THE MEETING MATERIALS ON-LINE?

 

   LOGO

The Meeting Materials can be viewed online at www.meetingdocuments.com/astca/ema as of Monday, April 8, 2019 for a period of one year following the Meeting, or at www.SEDAR.com

 

   LOGO

HOW CAN I OBTAIN A PAPER COPY OF THE MEETING MATERIALS?

 

   LOGO

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 3 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 2:00 p.m. Atlantic time on Thursday, May 2, 2019. To receive the Meeting Materials prior to the Meeting you should make your request before 2:00 p.m. Atlantic time on Monday, May 6, 2019.

Requests for paper copies of the Meeting Materials can be made until one year following the Meeting.


LOGO

 

   LOGO

WHAT MATTERS ARE BEING RECEIVED OR VOTED ON AT THE MEETING?

 

   LOGO

Shareholders are being asked to vote on the following items of business:

 

 

MEETING BUSINESS ITEM

 

  

 

INFORMATION CIRCULAR REFERENCE

 

 

  1.  Election of Directors – elect directors of the Company for the ensuing year.

 

  

 

See page 5 of the Information Circular for more information

 

  2.  Appointment of Auditors – appoint Ernst & Young LLP as auditors for the ensuing year.

 

  

 

See page 6 of the Information Circular for more information

  3.  Authorize Remuneration of Auditors – authorize the directors to fix the remuneration of the Auditors.

  

 

See page 6 of the Information Circular for more information

  4.  Say on Pay – an advisory resolution on the Company’s approach to executive compensation.

 

  

 

See page 6 of the Information Circular for more information

All Shareholders are reminded to review the Information Circular and 2018 Annual Report before voting.

 

   LOGO

HOW DO I VOTE MY SHARES?

 

   LOGO

You may vote by Internet, telephone, posted mail, delivered mail, e-mail or fax. Details of the methods for voting can be found on your accompanying voting instruction form. You will need your control number contained in the voting instruction form in order to vote by telephone or via the internet.

To be valid, proxies or voting instructions must be received by no later than 2:00 p.m. Atlantic Time on Monday, May 13, 2019 or, if the Meeting is adjourned or postponed, by 2:00 p.m. Atlantic Time two business days before the reconvened meeting date (or proxy deadline). Emera reserves the right to accept late voting instructions and to waive the proxy deadline, with or without notice, but is under no obligation to accept or reject any particular late voting instruction.

 

   LOGO

WHO CAN I CONTACT IF I HAVE QUESTIONS ABOUT NOTICE & ACCESS?

 

   LOGO

Shareholders with questions about notice and access can call toll free at 1-888-433-6443 (1-416-682-3801 for holders outside of Canada and the United States) or fulfilment@astfinancial.com

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