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, 2024
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 12, 2024 | By: | /s/ Brian Curry | ||||
Name: Brian Curry | ||||||
Title: Corporate Secretary |
EXHIBIT INDEX
Exhibit 99.1
Notice of Annual Meeting of Common Shareholders and Management Information Circular Thursday, May 23, 2024
Table of Contents
Notice of Emeras 2024 Annual Meeting of Shareholders |
7 | |||
Management Information Circular |
8 | |||
Annual Meeting of Shareholders |
9 | |||
Voting Information |
10 | |||
Business of the Meeting |
13 | |||
Director Nominees |
16 | |||
Additional Information |
29 | |||
Corporate Governance |
32 | |||
Corporate Governance Practices |
33 | |||
Board of Directors About the Board |
34 | |||
Strategic Oversight |
43 | |||
Risk Management |
49 | |||
Ethical Business Conduct |
50 |
Transparency and Disclosure |
51 | |||
Committees of the Board of Directors |
53 | |||
Director Compensation |
60 | |||
Additional Information |
64 | |||
Executive Compensation |
65 | |||
Message from the Management Resources and Compensation Committee to Our Shareholders |
66 | |||
Statement of Executive Compensation |
68 | |||
Compensation Discussion and Analysis |
74 | |||
Performance Graph |
93 | |||
NEO Summary Compensation Table |
95 | |||
Appendix A Emera Incorporated Board of Directors Charter |
109 |
FORWARD-LOOKING INFORMATION
This Circular contains forward-looking information and forward-looking statements within the meaning of applicable securities laws (collectively, forward-looking information). Words such as anticipates, believes, budget, could, estimates, expects, forecast, intends, may, might, plans, projects, schedule, should, targets, will, would and similar expressions are often intended to identify forward-looking information, although not all forward-looking information contains these identifying words. References to Emera in this section include references to the subsidiaries of Emera.
The forward-looking information includes, without limitation, statements which reflect the current view of Emeras management with respect to Emeras objectives, plans, financial and operating performance, carbon dioxide emissions reduction goals, business prospects and opportunities. All such forward-looking information is provided pursuant to safe harbour provisions contained in applicable securities laws.
The forecasts and projections that make up the forward- looking information are based on reasonable assumptions which include, but are not limited to: the receipt of applicable regulatory approvals and requested rate decisions; expectations regarding the nature, timing and costs of capital investments of Emera and its subsidiaries; continued investment in solar, wind and hydro generation; sufficient liquidity and capital resources; the absence of significant changes in government energy plans and environmental laws and regulations that may materially affect Emeras operations and cash flows; and sufficient human resources to deliver service and execute Emeras capital investment plan.
The forward-looking information is subject to risks, uncertainties and other factors that could cause actual results to differ materially from historical results or results anticipated by the forward-looking information. Factors that could cause results or events to differ from current expectations include, but are not limited to: regulatory and political risk; changes in economic conditions; liquidity and capital market risk; changes in credit ratings; future dividend growth; timing and costs associated with certain capital investments; supply chain risk; global climate change; weather risk, including higher frequency and severity of weather events; risk of wildfires; regulatory and government decisions, including changes to environmental legislation; uncertainties associated with infectious diseases, pandemics and similar public health threats; 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. For additional information with respect to certain of these risks or factors, refer to the continuous disclosure materials filed from time to time by Emera with Canadian securities regulatory authorities and the United States Securities and Exchange Commission. All such forward-looking information 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.
About Emera Data is as of December 31, 2023, unless otherwise indicated. From a single electric utility in Nova Scotia, Emera has grown into an energy leader serving customers in Canada, the US and the Caribbean. Our teams are focused on delivering cleaner, reliable energy to our customers, as we work toward our vision to achieve net-zero carbon emissions by 2050. We primarily invest in regulated electric and gas utilities, driving predictable returns and steady growth for our investors, enabling us to reinvest in our teams, our companies and our communities. $39B total assets $7.6B revenue 2.5M customers 7,300 employees 6 electric and natural gas utilities 94% shareholder support in 2022 Say on Pay vote 98% average vote in favour of the election of our Director Nominees for 20231 1 In total, 127,141,534 votes were cast out of a possible 271,424,515, representing 46.84 per cent. The highest vote in favour was 99.72 per cent and the lowest was 90.42 per cent. EMERA INCORPORATED 1
Notice of Annual Meeting of Common Shareholders and Management Information Circular Who We Are OUR PURPOSE Energizing modern life and delivering a cleaner energy future for all. OUR VISION To be the energy provider of choice for our customers, the employer of choice for our people and a preferred choice for investors. OUR VALUES Our core values shape our culture and guide our work every day. We put safety above all else. We put customers at the centre of everything we do. We value candour, respect and collaboration. We care for each other, the environment and our communities. We set a high bar and take on big things. OUR STRATEGY We are focused on safely delivering cleaner, reliable energy at a pace thats balanced with the cost impacts for our customers.
Why Invest in Emera Through our proven strategy and our portfolio of high-quality, regulated utilities, our expert teams across Emera continue to drive long-term value for shareholders. STRONG, SUSTAINABLE STRATEGY 18% of Board Director Nominees for 2024 identify as members of a diverse group, other than gender4 $5.4B (62%) of $9B capital plan to 2026 committed to decarbonization and reliability 47% reduction in CO2 emissions since 20055 $12M invested in our communities in 2023 0.25 Lost Time Injury Rate down 11% from 2022 (0.28) and a 24% improvement over 5-year average (0.33) 1 Emeras capital investment plan includes $240 million equity investment in 2024. 2 Based on December 29, 2023, share price of $50.30. 3 Based on 2023 adjusted net income, excluding Corporate costs of $356 million and including holding company interest costs. Adjusted net income is a non- GAAP measure, which does not have standardized meaning under USGAAP. For more information and a reconciliation to the nearest GAAP measure, refer to Non-GAAP Financial Measures and Ratios in Emeras Q4 2023 MD&A. 4 One Director Nominee identifies as a racialized person and one Director Nominee identifies as a member of the LGBTQ2SI+ community. 5 Undergoing final review and verification
Notice of Annual Meeting of Common Shareholders and Management Information Circular Letter from the Chair and the CEO Fellow shareholders, Throughout 2023, many of the global economic challenges we faced in 2022 continued to have an impact across all industries and sectors, including energy. As unfavourable weather and higher interest rates softened Emeras annual financial results, we continued making investments to safely deliver cleaner, reliable energy at a pace thats balanced with the cost impacts for our customers, while also continuing to provide long-term value for our shareholders. FOCUS ON CLEANER, RELIABLE ENERGY Our teams accomplished a lot in the year as we safely executed on a nearly $3 billion capital program the largest annual capital program in our history, with approximately two- thirds focused on decarbonization and reliability initiatives. This investment is driving our progress on reducing CO2 emissions and replacing coal with cleaner, lower-carbon sources of energy. Since 2005, weve reduced our CO2 emissions across Emera by 47 per cent and our use of coal in generation (GWh) by 77 per cent. Jackie Sheppard Chair, Emera Inc. Board of Directors Scott Balfour President and CEO, Emera Inc. 4 EMERA INCORPORATED
Notice of Annual Meeting of Common Shareholders and Management Information Circular
Much of this progress is taking place in our two largest utilities Tampa Electric and NS Power. Thanks to increased solar and natural gas generation, coal made up less than 4 per cent of the generation last year at Tampa Electric and its down by more than a third over 2022. At NS Power, generation from coal and petcoke was nearly 25 per cent less in 2023 compared to the previous year and is down more than 60 per cent since 2005. This is due in large part to strong energy flows across the Maritime Link that helped NS Power reach 40 per cent renewables in 2023.
Whether its investing to meet our expanding customer base, decarbonizing our generation mix, increasing reliability or modernizing the grid, we are investing to deliver for our customers and communities, and in doing so we are bringing value to our shareholders. As evidenced by our forecasted 7-8 per cent rate-base growth over the next three years, the opportunities to grow our business are robust.
COMMITMENT TO SAFETY
Our dedication to the safety of our teams and communities continued throughout 2023. Across Emera, we all play an important role as we strive to be predictably safe by relentlessly pursuing strong safety leadership, robust safety systems and intentioned safety culture.
Last year, we continued to improve on our overall safety performance. Our lost time injury rate improved by 24 per cent compared to our average over the last five years, achieving our best-ever level of safety performance. While we are proud of this achievement, we remain vigilant and never lose sight of the work required each and every day to keep each other safe.
GOVERNANCE
The strong governance and risk management provided by our Board of Directors is central to how we operate across Emera.
In 2023, the Board continued working with management to ensure Emera remains focused on, and well positioned to, deliver on its strategic priorities. Through the work of the Risk and Sustainability Committee (RSC), the Board continued to oversee Emeras approach to the clean energy transition and our Climate Commitment Progress. Through the robust tracking tool developed by the team, the RSC regularly reviews our progress and assesses risks in achieving our climate goals.
To support our energy transition efforts, Emera formed a cross-functional Task Force that is actively monitoring and preparing for mandatory climate-related and other sustainability disclosures that are currently under consideration.
There are some changes to our Board of Directors. We would like to acknowledge long-time Director Andrea Rosen who is stepping down from the Emera Board this year and not standing for re-election at the Annual Meeting. Since joining the Board in 2007, Andreas leadership experience, financial acumen and exceptional knowledge of investment and commercial banking have been of significant value to Emera. We thank Andrea for her service and wish her continued success.
We are pleased to welcome Brian Porter to the Board as of March 6, 2024. Brian has more than 40 years experience in the banking sector, including serving as President and Chief Executive Officer of the Bank of Nova Scotia (Scotiabank) from 2013 until his retirement in 2023. Brians extensive expertise in capital markets, corporate strategy, driving growth and executive leadership of a public company will be of great benefit to the Emera Board. Welcome, Brian.
FINANCIAL RESULTS
We reported annual adjusted earnings of $809 million and adjusted earnings per share (EPS)1 of $2.96 for 2023. While these results were down slightly from 2022, we still delivered a 5.3 per cent average annual increase in adjusted EPS over the last three years.
Our regulated utilities, particularly those in Florida, continue to drive our earnings growth. Tampa Electrics earnings have increased an average of nearly eight per cent per year since 2020, while earnings at Peoples Gas have increased on average 15 per cent per year over the same period.
In line with our commitment to providing value to our shareholders over the long term, we raised our dividend by four per cent in 2023, continuing our more than 17-year history of growing our dividend. And weve delivered annualized dividend growth of 5.4% since 2000.
1 | Adjusted net income and adjusted EPS are non-GAAP measures, which do not have standardized meaning under USGAAP. For more information and a reconciliation to the nearest GAAP measure, refer to Non-GAAP Financial Measures and Ratios in Emeras Q4 2023 MD&A. |
EMERA INCORPORATED | 5 |
Notice of Annual Meeting of Common Shareholders and Management Information Circular
Overall, 2023 was not a strong year for total returns in North American utility stocks. In Canada, the TSX Capped Utilities Index underperformed against the broader TSX Index by 11.6 per cent. In the US market, the utilities index had its worst performance in 50 years when compared to the S&P 500. Emeras Total Shareholder Return (TSR) for 2023 was 2.5 per cent, outperforming both the Canadian and US utility indices. Taking a longer view, our 10-year TSR ended the year at an annualized return of 10 per cent. Despite a weak market in 2023, were confident the path we are on will support our continued growth. For additional information about our relative TSR performance, see the performance graph on page 93 of this Circular.
We continue to focus on strengthening our balance sheet, while growing our rate base by 7-8 per cent per year in the near term. With the benefit of the broader industry trends of electrification, continued decarbonization and investments in reliability, we remain confident in the health and stability of our business and in our ability to continue to deliver an increase in earnings per share in 2024 and beyond.
2024 ANNUAL MEETING
On behalf of Emeras Board of Directors and management team, we are pleased to invite you to our 2024 Annual General Meeting (AGM) of Shareholders. Our AGM taking place virtually on May 23, 2024, at 2:00 p.m. (Atlantic time) via live webcast only. Details on how to participate in the virtual meeting are described in this Circular on page 10 and will be available on our website at http://www.emera.com/investors.
As a valued shareholder, you have several options to have your questions answered at the AGM. You can submit questions during the virtual meeting, or in advance of the meeting by contacting AGM@emera.com, or by using the mailing address provided below.
Lastly, we strongly encourage you to take advantage of the option to vote in advance by proxy. Information on how to do this can be found on page 12 of this Circular.
If you have any questions regarding our Annual Meeting of Shareholders, please contact Emeras Corporate Secretary, Brian Curry:
Mail P.O. Box 910, Halifax, Nova Scotia, B3J 2W5
Phone 1-800-358-1995 from anywhere in North America
Email AGM@emera.com
THANK YOU
We appreciate feedback from our shareholders, and we are committed to providing opportunities to engage.
We encourage you to review this information and exercise your right to vote at our AGM. Our AGM is an important way for us to engage with shareholders, so that your views can be expressed and your votes can be counted.
On behalf of the Board and management team, thank you for your ongoing confidence in Emera. |
Jackie Sheppard Chair, Emera Inc. Board of Directors |
Scott Balfour President and Chief Executive Officer, Emera Inc. |
6 | EMERA INCORPORATED |
Notice of Annual Meeting of Common Shareholders and Management Information Circular
Notice of Emeras 2024 Annual Meeting of Shareholders
When:
Thursday, May 23, 2024, 2:00 p.m. (Atlantic time)
How:
Virtual-only meeting via live video webcast at https://web.lumiagm.com/407390256
Password: emera2024 (case sensitive)
Agenda:
The meeting will cover the following items of business:
1. | Receiving the audited financial statements for the year ended December 31, 2023 and the auditors report thereon; |
2. | Electing Directors to serve until the next Annual Meeting of Shareholders; |
3. | Appointing Auditors; |
4. | Authorizing the Directors to establish the Auditors fee; and |
5. | Considering an advisory resolution on the Companys approach to executive compensation. |
The accompanying Management Information Circular provides detailed information on these items.
Who:
Emera shareholders as of close of business on March 26, 2024 (the Record Date) have the right to receive notice of and vote at the meeting or any adjournment.
How to Vote:
| Participate and vote virtually in the meeting by visiting https://web.lumiagm.com/407390256 and use password: emera2024 (case sensitive). Please note, beneficial (non-registered) owners will only be able to vote virtually or ask questions through the live webcast if they are duly appointed and registered as proxyholders. |
| If you do not plan to participate in the meeting: |
| Mail your proxy or voting instruction form using the postage-paid, pre-addressed envelope provided. |
| Vote by telephone or via internet (see the proxy or voting instruction form). Proxies must be received prior to 5:00 p.m. Atlantic time on Tuesday May 21, 2024, or if the meeting is adjourned, or postponed, 5:00 p.m. Atlantic time two business days prior to the reconvened meeting date. |
Questions:
Please contact us 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.
By order of the Board of Directors,
Brian C. Curry
Corporate Secretary
EMERA INCORPORATED | 7 |
Notice of Annual Meeting of Common Shareholders and Management Information Circular
Management Information Circular
All information is as of March 20, 2024
(unless otherwise noted)
You are receiving Emeras Management Information Circular (the Circular) because you held common shares of Emera Inc. (TSE: EMA) as of March 26, 2024 (the Record Date). You are entitled to receive notice of and vote at our Annual Meeting of Shareholders on Thursday, May 23, 2024 at 2:00 p.m. Atlantic time (the Meeting or Annual Meeting). Only shareholders of record at the close of business on the Record Date can 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 286,280,145 common shares.
In this Circular:
| we, us, our, Company and Emera mean Emera Inc. |
| you, your and shareholder refer to holders of Emera common shares |
| shares and Emera shares mean common shares of Emera, unless otherwise indicated |
| Board of Directors or Emeras Board or the Board means the Board of Directors of Emera Inc., unless otherwise indicated |
| all dollar amounts are in Canadian dollars, unless indicated otherwise |
| all information is as of March 20, 2024, unless otherwise noted |
Meeting Materials and Notice and Access
Canadian securities rules called Notice and Access permit us to provide electronic access to this Circular and the 2023 Annual Report (the Meeting Materials) instead of sending you paper copies. We are sending Meeting Materials to registered holders and beneficial owners using Notice and Access. The notice also provides instructions on voting by proxy at the Meeting and how to request a paper copy of the Meeting Materials.
Shareholders who have previously provided instructions to receive paper copies of Meeting Materials have been sent 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 and management of Emera for use at the Meeting. All shareholders 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.
We have retained TMX Investor Solutions Inc. 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 is covered by Emera and is not expected to exceed $50,000.
Your vote is important. We encourage all shareholders to review this Circular carefully and exercise your vote. Details on how to vote are included on page 10.
8 | EMERA INCORPORATED |
Notice of Annual Meeting of Common Shareholders and Management Information Circular
1. Annual Meeting of Shareholders
This section includes everything you need to know about your participation in the meeting.
|
IN THIS SECTION | 1.1 VOTING INFORMATION | 10 | ||
1.2 BUSINESS OF THE MEETING | 13 | |||
1.3 DIRECTOR NOMINEES | 16 | |||
1.4 ADDITIONAL INFORMATION | 29 |
EMERA INCORPORATED | 9 |
Notice of Annual Meeting of Common Shareholders and Management Information Circular
1.1 | Voting Information |
MEETING DETAILS
Emeras 2024 Annual Meeting is a virtual-only meeting.
You can participate in the Meeting online at https://web.lumiagm.com/407390256, using password: emera2024 (case sensitive).
VOTING DETAILS AND INSTRUCTIONS
You are eligible to receive notice and vote at the Meeting if you are a shareholder as of March 26, 2024 (the Record Date). You can vote in advance or during the Meeting.
If you have shares registered in your own name, then you are a registered shareholder. | If your shares are listed in the name of a nominee, then you are a beneficial or non-registered shareholder. For example, if an account statement is provided to you by a broker, then it is likely that those shares will not be registered in your name and are likely registered under the brokers 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. |
Registered shareholders and duly appointed proxyholders (including non-registered shareholders who have duly appointed themselves as proxyholder) can participate in and vote at the Meeting.
Non-registered shareholders who do not duly appoint themselves as proxyholder may still attend the Meeting as guests. Guests can listen to the Meeting, but will not be able to vote at the Meeting or ask questions.
It is important to note that the Meeting is virtual-only via live video webcast and you will not be able to attend in person. We recommend logging in online at least 15 minutes prior to the start of the Meeting. To help ensure that your vote is recorded, make sure that you are connected to the internet at all times. It is your responsibility to ensure internet connectivity for the duration of the Meeting. Please ensure you use the latest versions of Chrome, Safari, Edge or Firefox (please do not use Internet Explorer). Please note that internal network security protocols, including firewalls and VPN connections, may block access to the virtual meeting technology. If, during the Meeting, participants experience any difficulty connecting, they should ensure their VPN setting is disabled or use their computer on a network that is not restricted to security settings of a participants organization.
Shareholders are encouraged to vote in advance of the Meeting as described below under the heading How to Vote in Advance, particularly if they are worried about their ability to remain connected to the internet for the duration of the Meeting.
HOW TO VOTE DURING THE MEETING
Registered Shareholders and Proxyholders
Registered shareholders can participate in the Meeting by logging in to https://web.lumiagm.com/407390256 and entering their 13-digit Control Number as their username, using the password: emera2024 (case sensitive).
If you are a registered shareholder and have appointed a proxyholder to act on your behalf at the Meeting, you must register your proxyholder prior to the proxy deadline. Once your proxyholder has been registered, they will receive a Control Number from TSX Trust Company (TSX Trust) to access the virtual meeting. If you do not register your proxyholder, your proxyholder will not receive a Control Number to log in to the Meeting. For additional information on appointing a proxyholder, please see How to Vote in Advance Registering Your Proxyholder below.
Proxyholders for all shareholders can participate in the Meeting by logging in in the same manner as for registered shareholders (as described above) and entering the Control Number provided to the proxyholder by TSX Trust.
10 | EMERA INCORPORATED |
Notice of Annual Meeting of Common Shareholders and Management Information Circular
Beneficial (or Non-Registered) Owners
Non-registered shareholders wishing to participate in the Meeting must:
1. | Appoint themselves as proxyholder; |
2. | Register themselves as proxyholder; and |
3. | Access the meeting as a proxyholder using the Control Number received after registering as a proxyholder. |
If you do not register yourself as proxyholder, you will not receive a Control Number in order to log into the Meeting. The Control Number included in any voting instruction form sent to you will not enable you to log in to the Meeting. A new Control Number will be needed to log in, and one will be issued to you upon registering yourself as a proxyholder.
In order to appoint yourself as a proxyholder, follow the instructions in the form of proxy or voting instruction form sent to you by your intermediary. In most cases, you can simply insert your own name in the form of proxy or voting instruction form, sign it and return it in the envelope provided or you can make the appointment online. Do not complete the voting instructions, as you will be voting at the Meeting. However, many Objecting Beneficial Owners located in the United States instead will need to: (i) send a request to their intermediary or its agent to send them a legal proxy appointing them as proxyholder; and (ii) promptly, following receipt of the legal proxy, submit the legal proxy to TSX Trust Company, Proxy Department, P.O. Box 721, Agincourt, ON, M1S 0A1 prior to 5:00 p.m. Atlantic time on Tuesday, May 21, 2024.
Once a beneficial or non-registered owner has been appointed a proxyholder and has registered as proxyholder, they will receive a Control Number from TSX Trust to access the Meeting. The beneficial owner should follow the instructions under Registered Shareholders and Proxyholders above to log in to the virtual meeting as a proxyholder.
There are two kinds of beneficial (non-registered) owners: (i) Non-Objecting Beneficial Owners those who do not object to their name being made known to the issuers of the shares that they own; and (ii) Objecting Beneficial Owners those who object to their name being made known to the issuers of shares that they own.
Non-Objecting Beneficial Owners
Non-Objecting Beneficial Owners will receive a voting instruction form from Emeras registrar and transfer agent, TSX Trust.
This is to be completed and returned to TSX Trust in the envelope provided. In addition, TSX Trust provides both telephone voting and internet voting as described on the voting instruction form.
Objecting Beneficial Owners
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.
Please note that 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 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 (with sufficient time for your intermediary to act on your instructions prior to the proxy cut-off). If you wish to attend virtually and vote your shares at the Meeting, follow the instructions for doing so provided by your broker or agent.
How Can I Ask Questions at the Meeting?
Shareholders will have an opportunity to ask questions at the Meeting through a chat box in the online Meeting platform. Questions received from shareholders will be read by the chair of the Meeting or a designee of the chair and responded to by a representative of Emera at the applicable point in the Meeting or in the question and answer session.
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Notice of Annual Meeting of Common Shareholders and Management Information Circular
The chair of the Meeting will decide on the amount of time allocated to each question and will have the right to limit or consolidate questions from shareholders in order to help ensure as many shareholders as possible will have the opportunity to ask questions, and to reject questions that do not relate to the business of the Meeting or which are determined to be inappropriate or otherwise out of order.
Who Do I Contact If I Cannot Log In to the Meeting?
If you have any difficulties logging in to the Meeting online, please contact LUMIs online shareholder meeting email support via the address: support-ca@lumiglobal.com.
Even if you currently plan to participate in the Meeting, we encourage you to vote your shares in advance so that your vote will be counted in the event you experience any difficulties.
HOW TO VOTE IN ADVANCE
You can appoint a proxyholder in advance of the Meeting to attend the Meeting and vote your shares for you.
Registering Your Proxyholder
Registered shareholders and beneficial (or non-registered) owners wishing to appoint a proxyholder to participate virtually in the Meeting (including beneficial or non-registered owners wishing to appoint themselves as proxyholder to participate in the Meeting) must contact TSX Trust, Emeras registrar and transfer agent, before 5:00 p.m. Atlantic time on Tuesday, May 21, 2024 to obtain a new Control Number to use to access the virtual meeting by:
(i) | calling: |
1-866-751-6315 (within North America); or
1-416-682-3860 (outside of North America); or
(ii) | going to TSX Trusts website at https://www.tsxtrust.com/control-number-request to request the Control Number by completing an electronic form. This form, once completed and submitted online, will generate a message to TSX Trust to send the Control Number to the designated proxyholder. |
Shareholder Proxy Materials
These security holder materials are being sent to both registered and non-registered owners of the securities. If you are a non-registered owner, and the issuer or its agent has sent these materials directly to you, your name, address and information about your holdings of securities have been obtained in accordance with applicable securities regulatory requirements from the intermediary holding on your behalf. Emera has arranged for its registrar and transfer agent, TSX Trust, to send materials directly to Non-Objecting Beneficial Owners in accordance with National Instrument 54-101 Communication with Beneficial Owners of Securities of a Reporting Issuer.
By choosing to send these materials to you directly, Emera (and not the intermediary holding on your behalf) has assumed responsibility for: (i) delivering these materials to you as a Non-Objecting Beneficial Owner; and (ii) executing your proper voting instructions. Please return voting instructions as specified in the request for voting instructions.
Emera will bear costs of delivering shareholder proxy materials and the request for voting instructions, as applicable, to registered shareholders, Non-Objecting Beneficial Owners and Objecting Beneficial Owners.
Appointment and Revocation of Proxies
The persons named as proxyholders in the enclosed proxy are Jackie Sheppard, Chair of the Board, Scott Balfour, President and Chief Executive Officer (CEO), and Brian Curry, Corporate Secretary of the Company.
For a vote by proxy or voting instruction form to be counted, it must be received prior to 5:00 p.m. Atlantic time on Tuesday, May 21, 2024, or if the meeting is adjourned or postponed, by 5:00 p.m. Atlantic time two business days prior to the reconvened meeting date. Note, non-registered owners must provide their voting instructions to their intermediary in advance of this deadline so that the intermediary may act on the voting instructions.
The Company reserves the right to accept late proxies and to waive the proxy cut-off with or without notice, but is under no obligation to accept or reject a late proxy. For Canadian residents, a postage-paid, pre-addressed envelope is provided for this purpose.
12 | EMERA INCORPORATED |
Notice of Annual Meeting of Common Shareholders and Management Information Circular
You may vote by proxy or voting instruction form via mail, the internet or telephone.
Completion of a proxy gives discretionary authority to the proxyholder to vote as they see fit in respect of amendments to matters identified in the Notice, and other matters that may properly come before the Meeting or any adjournment or postponement thereof, whether or not the amendment or other matter that comes before the Meeting is, or is not, routine and whether or not the amendment or other matter that comes before the Meeting is contested. Management of the Company is not aware of any amendments or other matters to be presented for action at the Meeting.
If you appoint Ms. Sheppard, Mr. Balfour or Mr. Curry 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 Director nominees named in this Circular; |
| Appointment of Ernst & Young LLP as Auditors; |
| Authorization of the Directors to establish the Auditors fee; |
| Advisory resolution on the Companys approach to executive compensation. |
They will vote in accordance with their best judgement 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 persons name in the space provided on the proxy or voting instruction form. That person is your proxyholder and must participate and vote at the Meeting for your vote to count. You will also need to register this person with TSX Trust; see Registering Your Proxyholder.
You may revoke your proxy by providing new voting instructions in a new proxy or voting instruction form with a later date, or at a later time if you are voting on the internet or by telephone. Any new voting instructions, however, will only take effect if received prior to 5:00 p.m. Atlantic time on Tuesday, May 21, 2024, or if the meeting is adjourned or postponed, 5:00 p.m. Atlantic time two business days prior to the reconvened meeting date. You may also revoke your proxy without providing new voting instructions by giving written notification addressed to Mr. Brian Curry, Corporate Secretary, P.O. Box 910, Halifax, Nova Scotia B3J 2W5, no later than the last business day preceding the day of the Meeting or preceding the day of any postponement or adjournment thereof or to the chair of the Meeting on the day of the Meeting or the day of any postponement or adjournment thereof or in any other manner permitted by law. If your new voting instructions (including the appointment of a new proxyholder) are received after the proxy cut-off described above, they may only be effective to revoke your previously provided instructions. Similarly, registered shareholders may participate in the Meeting and vote their shares and, if they do so, any voting instructions previously given by such persons for such shares will be revoked.
Restriction on Share Ownership and Voting
Under Nova Scotia legislation, no Emera shareholder may own or control, directly or indirectly, more than 15 per cent of the outstanding voting shares. This restriction may be enforced by limiting non-complying shareholders voting rights (including by disqualifying or deeming votes to have not been cast by such non-complying shareholders), dividend rights and transfer rights. Shareholders may be required, at any time, to furnish a statutory declaration to verify the number of shares held to ensure compliance with this restriction.
If you have any questions about the share ownership and voting restriction, please contact the Corporate Secretary.
1.2 | Business of the Meeting |
Our consolidated financial statements for the year ended December 31, 2023, will be received together with the report of the auditor. These consolidated financial statements are contained in our 2023 Annual Report. You will find a copy of our 2023 Annual Report on our website (www.emera.com) and on SEDAR+ (www.sedarplus.com).
EMERA INCORPORATED | 13 |
Notice of Annual Meeting of Common Shareholders and Management Information Circular
You will also have the opportunity to vote on the following items:
1. | Election of the Board of Directors: The 11 nominees proposed for election as Directors at the 2024 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 Corporate Governance section of this Circular. |
All nominees are currently Directors of the Company. Each nominee has indicated their 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. Curry intend to vote proxies received FOR the 11 nominees unless a shareholder instructs otherwise in their proxy.
The Board of Directors recommends you vote FOR the election of each of the 11 nominated Directors.
2. | Appointment of Auditors: The Audit Committee has assessed the performance and independence of Ernst & Young LLP (EY) and the Board of Directors recommends that EY be re-appointed as auditor of the Company and serve until the next Annual Meeting. |
The independence of the auditors is of utmost importance to the Audit Committee. Consistent with best practices and its mandate, the Audit Committee annually reassesses the performance and independence of the auditors, with a comprehensive review conducted every five years. These reviews align with the recommendations of the Chartered Professional Accountants of Canada (CPA Canada), the Canadian Public Accountability Board (CPAB) and the Institute of Corporate Directors. CPA Canada and CPAB recommend periodic comprehensive reviews as the preferred alternative to mandatory firm rotation or re-tendering to address the threat of institutional familiarity and to enhance audit quality.
To help ensure independence, the Audit Committee also reviews and pre-approves any non-audit services to be provided by EY and has a policy restricting the hiring by the Company of former EY partners and employees.
In recommending the appointment of auditors, the Audit Committee considers the benefits and risks of auditor tenure, and the controls and processes in place to help ensure the auditors independence, such as mandatory partner rotations. The lead audit partner with EY is rotated at least every five years, with the current lead audit partner having commenced their rotation in 2021.
EY has been Emeras auditors since 1998. However, until 2018, PricewaterhouseCoopers served as auditors for Tampa Electric Company, Peoples Gas System, and New Mexico Gas Company, which together represent more than 70 per cent of the Companys total assets at the end of 2023. In addition, until 2012, Grant Thornton, LLP served as auditors for Nova Scotia Power Incorporated. In 2017, the Company initiated a competitive process for external audit services. The process was overseen by the Audit Committee, which selected EY as auditors for Emeras full business starting in 2018.
The recommendation to appoint EY as auditor for 2024 is based on a comprehensive review of EYs performance conducted by the Audit Committee in 2022, and an updated annual review by the Audit Committee in 2023.
Ms. Sheppard, Mr. Balfour and Mr. Curry intend to vote proxies received FOR the appointment of EY as auditors of the Company, to hold office until the close of the next Annual Meeting, unless a shareholder specifies their shares be withheld from voting.
The Board of Directors recommends you vote FOR the appointment of Ernst & Young LLP as auditors of the Company.
14 | EMERA INCORPORATED |
Notice of Annual Meeting of Common Shareholders and Management Information Circular
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 EY, during the last two fiscal years ended December 31, 2023 and December 31, 2022, were as follows: |
Service fee |
2023 ($) | 2022 ($) | ||||||
Audit fees |
$ | 3,910,266 | $ | 2,018,989 | ||||
Audit-related fees (1) |
174,410 | 19,600 | ||||||
Tax fees (2) |
39,450 | 337,999 | ||||||
All other fees |
75,000 | | ||||||
|
|
|
|
|||||
Total |
$ | 4,199,126 | $ | 2,376,588 | ||||
|
|
|
|
(1) | Audit-related fees for Emera relate to fees associated with agreed-upon procedures over rate-case filings and the audit of pension plans. |
(2) | Tax fees for Emera relate to tax compliance services and general tax consulting advice on various matters. |
The Auditors fees for EY in 2023 are reflective of market rates for professional services, which have increased substantially in recent years. The Auditors fees for 2022 were the last year in a five-year fee arrangement between the Company and EY.
Ms. Sheppard, Mr. Balfour and Mr. Curry intend to vote proxies received FOR the authorization of Directors to establish the Auditors fee for 2024, unless a shareholder instructs otherwise in their proxy.
The Board of Directors recommends that you vote FOR the authorization of Directors to establish the Auditors fee for 2024.
4. | Advisory Vote on Executive Compensation (say on pay): You will be asked to consider and approve, on an advisory basis, the resolution stated below on Emeras approach to executive compensation as disclosed in this Circular. This advisory vote forms an important part of the ongoing process of engagement between shareholders and the Board on executive compensation. At the 2022 and 2023 Annual Meetings, Emeras approach to executive compensation was approved with 94.64% in 2022 and 94.46% in 2023, respectively, of the votes cast FOR the advisory resolution on executive compensation. |
Our executive compensation programs are designed to attract, retain, motivate and reward high-calibre leaders to deliver strong performance in alignment with Emeras 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 executives 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 MRCCs report to you.
As our shareholder, on an advisory basis, you have the opportunity to vote FOR or Against our approach to executive compensation through the following resolution:
RESOLVED, on an advisory basis, and not to diminish the role and responsibilities of the Board of Directors, that the shareholders accept the approach to executive compensation disclosed in the Companys Management Information Circular delivered in advance of the 2024 Annual Meeting of Shareholders of Emera Incorporated.
Since your vote is advisory, it will not be binding on the Board; however, the Board, and in particular the MRCC, will seriously consider the outcome of the vote and may communicate with certain shareholders as a follow-up matter as part of its ongoing review of executive compensation.
Ms. Sheppard, Mr. Balfour and Mr. Curry intend to vote proxies received FOR the non-binding advisory resolution on executive compensation, unless otherwise instructed.
The Board of Directors recommends you vote FOR the non-binding advisory resolution on executive compensation.
EMERA INCORPORATED | 15 |
Notice of Annual Meeting of Common Shareholders and Management Information Circular
1.3 | Director Nominees |
There are 11 individuals nominated to serve on the Board. All Director nominees, except Mr. Balfour, are considered by the Board to be independent. Mr. Balfour is not considered independent because he is also the President and CEO of the Company. For more information about the Companys definition of independence, see Director and Chair Independence in the Corporate Governance section later in this Circular.
DIRECTOR NOMINEES AT A GLANCE
Name (1) |
Occupation | Age | Independent | Residency | % Votes in favour at 2023 AGM |
2023 Committees |
All Board meetings (5) |
Year Turning 72 years (6) |
||||||||||||||||||
Scott Balfour (2) |
Chief Executive Officer | 59 | No | Canada | 99.72 | N/A | 100 | % | 2036 | |||||||||||||||||
Director since 2018 |
||||||||||||||||||||||||||
James Bertram |
Corporate Director | 68 | Yes | Canada | 99.48 | HSE | 100 | % | 2028 | |||||||||||||||||
Director since 2018 |
MRCC | |||||||||||||||||||||||||
Henry Demone |
Corporate Director | 69 | Yes | Canada | 95.98 | MRCC (Chair) | 100 | % | 2027 | |||||||||||||||||
Director since 2014 |
NCGC | |||||||||||||||||||||||||
Paula Gold-Williams |
Corporate Director | 61 | Yes | United States | 99.55 | HSEC | 88 | % | 2035 | |||||||||||||||||
Director since 2022 |
Audit | |||||||||||||||||||||||||
Kent Harvey |
Corporate Director | 66 | Yes | United States | 99.24 | Audit (Chair) | 100 | % | 2030 | |||||||||||||||||
Director since 2017 |
HSEC | |||||||||||||||||||||||||
Lynn Loewen |
Corporate Director | 63 | Yes | Canada | 99.57 | Audit | 100 | % | 2033 | |||||||||||||||||
Director since 2013 |
HSEC | |||||||||||||||||||||||||
RSC | ||||||||||||||||||||||||||
Brian Porter (3) |
Corporate Director | 66 | Yes | Canada | N/A | N/A | N/A | 2030 | ||||||||||||||||||
Director since 2024 |
||||||||||||||||||||||||||
Ian Robertson |
Corporate Director | 64 | Yes | Canada | 99.65 | Audit | 100 | % | 2031 | |||||||||||||||||
Director since 2022 |
RSC | |||||||||||||||||||||||||
Jackie Sheppard (4) |
Corporate Director | 68 | Yes | Canada | 99.11 | Board (Chair) | 100 | % | 2028 | |||||||||||||||||
Director since 2009 |
||||||||||||||||||||||||||
Karen Sheriff |
Corporate Director | 66 | Yes | Canada | 99.42 | MRCC | 100 | % | 2030 | |||||||||||||||||
Director since 2021 |
RSC | |||||||||||||||||||||||||
NCGC | ||||||||||||||||||||||||||
Jochen Tilk |
Corporate Director | 60 | Yes | Canada | 99.05 | RSC (Chair) | 100 | % | 2035 | |||||||||||||||||
Director since 2018 |
MRCC | |||||||||||||||||||||||||
NCGC |
(1) | Information about each Director Nominee is current as of the date of this Circular, unless otherwise noted. |
(2) | Mr. Balfour, as President and CEO, does not serve as a member of any Committee but attends all Committee meetings. |
(3) | Mr. Porter was appointed in March 2024. |
(4) | Ms. Sheppard is not a member of any Board Committee but attends all Committee meetings as Chair of the Board. |
(5) | This reflects attendance at all scheduled Board meetings and special Board meetings scheduled on short notice. |
(6) | In the normal course, a Director who would be 72 years of age at the Annual Meeting would not be nominated for re-election. See Board Renewal in the Corporate Governance section later in this Circular. |
16 | EMERA INCORPORATED |
Notice of Annual Meeting of Common Shareholders and Management Information Circular
See pages 38 and 41 for more information about Director tenure and diversity, respectively.
DIRECTOR NOMINEE PROFILES
The profiles that follow provide important information on each of the 11 Director nominees, including age, municipality and country of residence, year first elected or appointed as a Director, principal occupation, education, skills and experience. (1)
Committee memberships and meeting attendance (where applicable) for meetings held in 2023, as well as any memberships on other public company boards in the last five years, is also provided.
Also included in the profiles, is information about the common shares and deferred share units (DSUs) of Emera held as of the last trading day of each year by each Director nominee for the past three years. The estimated value of each Director nominees common shares and DSU holdings is based on the following:
Year-end |
Closing price of Emera common shares ($) |
|||
December 31, 2021 |
63.22 | |||
December 30, 2022 |
51.75 | |||
December 29, 2023 |
50.30 |
All Director nominees are required to meet Emeras share ownership guideline. The information below details their status under the guideline. For further information regarding the required level of share ownership for Emeras Directors, see Director Share Ownership Guideline in the Corporate Governance section later in this Circular. For further information on the share ownership guidelines for the Companys executive officers, including Mr. Balfour, see Executive Share Ownership Requirements and Anti- Hedging Policy in the Statement of Executive Compensation later in this Circular.
(1) | Information about each Director Nominee is current as of the date of this Circular, unless otherwise noted. |
EMERA INCORPORATED | 17 |
Notice of Annual Meeting of Common Shareholders and Management Information Circular
SCOTT BALFOUR
Director Since: 2018 | Not Independent, President and CEO of Emera |
Halifax, Nova Scotia
Canada
Age: 59
Skills and Experience
| CEO/Senior Executive |
| Sustainability/ESG |
| Governance |
| Risk Management |
| Customer/Stakeholder |
| Energy Sector or Utility Sector |
| Strategic Planning, M&A or Growth Strategy |
| Talent Management and Executive Compensation |
| Financial Literacy and Accounting |
| Government Relations, Public Policy and Regulatory |
2023 Annual Meeting Votes for: 99.72%
Other Public Company Boards
(last five years)
| Martinrea International Inc. |
(June 2013 to June 2020) |
Mr. Balfour was appointed President and CEO of Emera and became a Director of the Board in 2018.
Mr. Balfour first joined Emera in 2012 as Chief Financial Officer (CFO), later becoming CEO. Before joining Emera, he held a variety of roles, including President and CFO at Aecon Group Inc., a Canadian publicly traded construction and infrastructure development company.
Mr. Balfour is a Director of many Emera subsidiaries and serves as Chair of the Boards of Tampa Electric Company, Nova Scotia Power Incorporated and Peoples Gas System, Inc. He also serves as Director of the Business Council of Canada. He is a former Director of Martinrea International Inc. and past-Chair of the Ontario Energy Association.
Mr. Balfour received his Master of Business Administration from the Richard Ivey School of Business at the University of Western Ontario. He earned a Bachelor of Business Administration (Honours) from Wilfrid Laurier University.
Mr. Balfours strong experience in finance, operations, and as a public company executive provide the foundation for his contribution to the Board and his leadership of Emera. His knowledge of capital markets, along with his experience in growing a business through the development and execution of strategy, and through mergers and acquisitions, as well as leading teams and structuring systems to manage that growth, are tremendous assets for Emera.
Board and Committee membership |
Attendance | Total | ||||||
Board (1) |
8 of 8 | 100 | % |
DSUs awarded and held |
||||||||
2023 share- |
Total 2023 change in value of all DSUs held ($) |
Market value of total DSU holdings ($) |
||||||
889,053 | 177,096 | 7,032,393 |
Emera Securities held (2) |
||||||||||||
2021 | 2022 | 2023 | ||||||||||
Common shares (3) |
63,242 | 72,392 | 76,190 | |||||||||
DSUs |
105,870 | 122,135 | 139,809 | |||||||||
Value of shares and DSUs ($) |
10,691,261 | 10,066,772 | 10,864,756 | |||||||||
Status under Executive Share Ownership Requirements (4) |
|
As President and CEO of Emera, Mr. Balfour is subject to Executive Share Ownership Requirements. This requires that he own shares and/or DSUs valued at no less than five times his salary. He owns shares and DSUs valued at 9.6x of the Executive Share Ownership Requirements. |
|
(1) | Mr. Balfour, as President and Chief Executive Officer, does not serve on any of the Board Committees but attends all Committee meetings. |
(2) | As stated on page 17, the information about the common shares and DSUs held by each Director nominee is as of the last trading day of each year for the past three years. |
(3) | Includes all shares controlled directly or indirectly by Mr. Balfour. |
(4) | For more information, see Executive Share Ownership Requirements and Anti-Hedging Policy in the Statement of Executive Compensation in this Circular. |
18 | EMERA INCORPORATED |
Notice of Annual Meeting of Common Shareholders and Management Information Circular
JAMES BERTRAM
Director Since: 2018 | Independent Director |
Calgary, Alberta
Canada
Age: 68
Skills and Experience
| CEO/Senior Executive |
| Sustainability/ESG |
| Governance |
| Customer/Stakeholder |
| Energy Sector or Utility Sector |
| Strategic Planning, M&A or Growth Strategy |
| Talent Management and Executive Compensation |
2023 Annual Meeting Votes for: 99.48%
Other Public Company Boards
(last five years)
| Keyera Corp. (March 2003 to present) |
| Methanex Corporation (October 2018 to present) |
Mr. Bertram has been Director of Emera since July 2018. He became a member of the Management Resources and Compensation Committee in November 2018. He was appointed Chair of the Health, Safety and Environment Committee in May 2019.
Mr. Bertram was CEO of Keyera Corp., one of Canadas leading publicly traded midstream oil and gas operators, from its inception in 1998 until 2015 when he became Executive Chair. He retired as an officer of Keyera in 2016. Prior to this, he was Vice President, Marketing for the worldwide operations of Gulf Canada.
Mr. Bertram is a corporate director and is the Chair of the Board of Keyera Corp. He is also a Director of Methanex Corporation, the worlds 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 in growing a business and completing major acquisitions, while also enabling consistent delivery of value to customers and shareholders, Mr. Bertram makes an important contribution to Emeras Board.
Board and Committee membership |
Attendance | Total | ||||||
Board |
8 of 8 | 100 | % | |||||
Health, Safety and Environment Committee (Chair) |
3 of 3 | 100 | % | |||||
Management Resources and Compensation Committee |
6 of 6 | 100 | % |
Total compensation |
||||||||
Fees earned in 2023 ($) |
All other compensation ($) | Total ($) | ||||||
295,500 |
Nil | 295,500 |
DSUs awarded and held |
||||||||
2023 share-based |
Total 2023 change in value of all DSUs held ($) |
Market value of total DSU holdings ($) |
||||||
295,500 |
(35,272 | ) | 1,583,099 |
Emera Securities held |
||||||||||||
2021 | 2022 | 2023 | ||||||||||
Common shares |
6,470 | 14,170 | 14,170 | |||||||||
DSUs |
18,723 | 24,325 | 31,473 | |||||||||
Value of shares and DSUs ($) |
1,592,701 | 1,992,140 | 2,295,850 | |||||||||
Status under share ownership guideline (1) |
|
Mr. Bertram owns shares and DSUs valued at over 8.3x the Annual Directors retainer; therefore, the guideline has been met. |
|
(1) | Under Emeras Director Share Ownership Guideline, a Director must own three times the total cash and equity-based annual Director retainer in Emera common shares or DSUs, or a combination of the two. For more information, see Director Share Ownership Guideline in the Corporate Governance section later in this Circular. |
EMERA INCORPORATED | 19 |
Notice of Annual Meeting of Common Shareholders and Management Information Circular
HENRY DEMONE
Director Since: 2014 | Independent Director |
Lunenburg, Nova Scotia
Canada
Age: 69
Skills and Experience
| CEO/Senior Executive |
| Sustainability/ESG |
| Governance |
| Customer/Stakeholder |
| Strategic Planning, M&A or Growth Strategy |
| Talent Management and Executive Compensation |
2023 Annual Meeting Votes for: 95.98%
Other Public Company Boards (last five years)
| Saputo Inc. (June 2012 to present) |
| High Liner Foods Inc. (August 1989 to May 2019) |
Mr. Demone joined Emeras Board in September 2014. At that time, he also became a member of the Management Resources and Compensation Committee, and became Chair of the Committee in May 2021. He was appointed to the Nominating and Corporate Governance Committee in May 2017.
Mr. Demone is the former Chair of High Liner Foods Inc. of Lunenburg, Nova Scotia, the leading North American processor and marketer of value-added frozen seafood. He became President of High Liner Foods Inc. in 1989. In 1992, he was appointed President and CEO, a position he held until May 2015. He was reappointed CEO of High Liner Foods on an interim basis from August 2017 until April 2018.
Mr. Demone is a corporate director and currently sits on the board of Saputo Inc., a Montreal-based dairy company that produces, markets and distributes a wide array of dairy products. He is past-Chair of the Fisheries Council of Canada and The Groundfish Forum, a global trade association representing industry leaders. He has served on the boards of Dover Industries Ltd. and Maritime Tel & Tel (Aliant). Mr. Demone was also the first non-United States citizen to be named Chair of the National Fisheries Institute, a United States national trade association.
Mr. Demone received his Bachelor of Science in Mathematics with honours from Acadia University.
In both public and private entities, Mr. Demone has extensive experience in strategic planning, global markets, and mergers and acquisitions. As a long-time business leader in Atlantic Canada, Mr. Demones robust business relationships and his solid reputation make him a valuable member of Emeras Board of Directors.
Board and Committee membership |
Attendance | Total | ||||||
Board |
8 of 8 | 100 | % | |||||
Management Resources and Compensation Committee (Chair) |
6 of 6 | 100 | % | |||||
Nominating and Corporate Governance Committee |
6 of 6 | 100 | % |
Total compensation |
||||||||
Fees earned in 2023 ($) |
All other compensation ($) | Total ($) | ||||||
295,500 |
Nil | 295,500 |
DSUs awarded and held |
||||||||
2023 share- awards ($) |
Total 2023 change in value of all DSUs held ($) |
Market value of total DSU holdings ($) |
||||||
160,000 | (55,003 | ) | 2,170,171 |
Emera Securities held |
||||||||||||
2021 | 2022 | 2023 | ||||||||||
Common shares |
9,062 | 9,062 | 9,062 | |||||||||
DSUs |
33,763 | 37,933 | 43,145 | |||||||||
Value of shares and DSUs ($) |
2,707,397 | 2,432,006 | 2,625,990 | |||||||||
Status under share ownership guideline (1) |
|
Mr. Demone owns shares and DSUs valued at over 9.5x the Annual Directors retainer; therefore, the guideline has been met. |
|
(1) | Under Emeras Director Share Ownership Guideline, a Director must own three times the total cash and equity-based annual Director retainer in Emera common shares or DSUs, or a combination of the two. For more information, see Director Share Ownership Guideline in the Corporate Governance section later in this Circular. |
20 | EMERA INCORPORATED |
Notice of Annual Meeting of Common Shareholders and Management Information Circular
PAULA GOLD-WILLIAMS
Director Since: 2022 | Independent Director |
San Antonio, Texas
United States
Age: 61
Skills and Experience
| CEO/Senior Executive |
| Sustainability/ESG |
| Governance |
| Risk Management |
| Customer/Stakeholder |
| Energy Sector or Utility Sector |
| Strategic Planning, M&A or Growth Strategy |
| Talent Management and Executive Compensation |
| Financial Literacy and Accounting |
| Government Relations, Public Policy and Regulatory |
2023 Annual Meeting Votes for: 99.55%
Other Public Company Boards (last five years)
| ReNew Energy Global Plc (August 2023 to present) |
Ms. Gold-Williams joined Emeras Board in February 2022. She became a member of the Audit Committee and the Health, Safety and Environment Committee in May 2022.
Ms. Gold-Williams is the former President and CEO of CPS Energy, a fully integrated electric and natural gas municipal utility based in San Antonio, Texas. Before becoming CEO in 2015, she served in positions of increasing responsibility during her 17-year career at CPS Energy, including Group EVP Financial & Administrative Services, CFO and Treasurer.
Ms. Gold-Williams is a corporate director and serves as Co-Chair of the Keystone Policy Center, having been a member of both the Policy Center and its Energy Board since 2016. She serves as an Energy Pillar Co-Chair of Dentons Global Smart Cities & Communities Initiatives and Think Tank. She also serves on the United States Secretary of Energys Advisory Board (SEAB) and is a member of the board of directors of ReNew Energy Global Plc, a renewable energy company based in India. Previously, Ms. Gold-Williams held other board positions, including First Vice Chair of the Electric Power Resource Institute (EPRI), a member and designated Chair Pro Tem of the Federal Reserve Bank of Dallas San Antonio Branch, and a past-Chair of the San Antonio Chamber of Commerce.
Ms. Gold-Williams has an Associate Degree in Fine Arts from San Antonio College. She has a Bachelor of Business Administration in accounting from St. Marys University in Texas. She earned her Master of Business Administration in Finance and Accounting from Regis University in Denver, Colorado. She is a Certified Public Accountant and a Chartered Global Management Accountant.
As the former President and CEO of CPS Energy, the largest municipally owned electric and natural gas utility in the United States, with a diverse mix of nuclear, coal, gas, wind, solar generation, and battery storage, Ms. Gold-Williams skills and experience in developing business strategies focused on consistently prioritizing customers, community, and employees is tremendously important to Emeras Board.
Board and Committee membership |
Attendance | Total | ||||||
Board |
7 of 8 | 88 | % | |||||
Health, Safety and Environment Committee |
3 of 3 | 100 | % | |||||
Audit Committee |
5 of 5 | 100 | % |
Total compensation |
||||||||
Fees earned in 2023 ($) |
All other compensation ($) | Total ($) | ||||||
330,090 |
Nil | 330,090 |
DSUs awarded and held |
||||||||
2023 share-based awards ($) |
Total 2023 change in value of all DSUs held ($) |
Market value of total DSU holdings ($) |
||||||
330,090 | (6,452 | ) | 563,549 |
Emera Securities held |
||||||||||||
2021 | 2022 | 2023 | ||||||||||
Common shares |
Nil | Nil | Nil | |||||||||
DSUs |
Nil | 4,450 | 11,204 | |||||||||
Value of shares and DSUs ($) |
Nil | 230,280 | 563,549 | |||||||||
Status under share ownership guideline (1) |
|
Ms. Gold-Williams owns shares valued at over 2x the Annual Directors retainer. She has until February 2025 to meet the share ownership guideline. |
|
(1) | Under Emeras Director Share Ownership Guideline, a Director must own three times the total cash and equity-based annual Director retainer in Emera common shares or DSUs, or a combination of the two. For more information, see Director Share Ownership Guideline in the Corporate Governance section later in this Circular. |
EMERA INCORPORATED | 21 |
Notice of Annual Meeting of Common Shareholders and Management Information Circular
KENT HARVEY
Director Since: 2017 | Independent Director |
New York, New York
United States
Age: 66
Skills and Experience
| CEO/Senior Executive |
| Governance |
| Risk Management |
| Energy Sector or Utility Sector |
| Strategic Planning, M&A or Growth Strategy |
| Financial Literacy and Accounting |
| Government Relations, Public Policy and Regulatory |
2023 Annual Meeting Votes for: 99.24%
Other Public Company Boards (last five years)
None
Mr. Harvey joined Emeras Board in November 2017 and was appointed to the Audit Committee at that time. He became Chair of the Audit Committee in June 2020. He has been a member of the Health, Safety and Environment Committee since May 2019.
Mr. Harvey is former CFO for San Francisco-based PG&E Corporation, 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 United States citizen. He holds a bachelors degree in economics and a masters degree in engineering, both from Stanford University. He volunteers as a crisis services provider at the Trevor Project, a United States non-profit organization that is focused on suicide prevention among LGBTQ youth.
Mr. Harvey is an experienced energy industry leader and strategic thinker with deep financial knowledge and strong expertise in United States markets, making him a significant asset to Emeras Board.
Board and Committee membership |
Attendance | Total | ||||||
Board |
8 of 8 | 100 | % | |||||
Audit Committee (Chair) |
5 of 5 | 100 | % | |||||
Health, Safety and Environment Committee |
3 of 3 | 100 | % |
Total compensation |
||||||||
Fees earned in 2023 ($) |
All other compensation ($) | Total ($) | ||||||
350,420 |
8,213 | 358,633 |
DSUs awarded and held |
||||||||
2023 share-based awards ($) |
Total 2023 change in value of all DSUs held ($) |
Market value of total DSU holdings ($) |
||||||
160,000 | (31,649 | ) | 1,316,130 |
Emera Securities held |
||||||||||||
2021 | 2022 | 2023 | ||||||||||
Common shares |
Nil | Nil | Nil | |||||||||
DSUs |
15,624 | 21,827 | 26,166 | |||||||||
Value of shares and DSUs ($) |
987,749 | 1,129,530 | 1,316,130 | |||||||||
Status under share ownership guideline (1) |
|
Mr. Harvey owns DSUs valued at over 4.7x the Annual Directors retainer; therefore, the guideline has been met. |
|
(1) | Under Emeras Director Share Ownership Guideline, a Director must own three times the total cash and equity-based annual Director retainer in Emera common shares or DSUs, or a combination of the two. For more information, see Director Share Ownership Guideline in the Corporate Governance section later in this Circular. |
22 | EMERA INCORPORATED |
Notice of Annual Meeting of Common Shareholders and Management Information Circular
LYNN LOEWEN, FCPA, FCA
Director Since: 2013 | Independent Director |
Westmount, Quebec
Canada
Age: 63
Skills and Experience
| CEO/Senior Executive |
| Sustainability/ESG |
| Governance |
| Risk Management |
| Customer/Stakeholder |
| Strategic Planning, M&A or Growth Strategy |
| Talent Management and Executive Compensation |
| Financial Literacy and Accounting |
| Government Relations, Public Policy and Regulatory |
2023 Annual Meeting Votes for: 99.57%
Other Public Company Boards (last five years)
| National Bank of Canada (2022 to present) |
Ms. Loewen has been a Director of Emera 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. In September 2021, she became a member of the Risk and Sustainability Committee.
Ms. Loewen is the former President of Minogue Medical Inc., a Canadian supplier of innovative medical technologies, supplies and equipment. From 2008 to 2011, she was President of Expertech Network Installation Inc., a Canadian network infrastructure service provider. She also 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. Earlier in her career, she was with Air Canada Jazz where she held positions of increasing responsibility, including Vice President of Corporate Services and CFO.
Ms. Loewen is a member of the Board of Directors of National Bank of Canada, a Canadian Chartered Bank, Chair of its Audit Committee and a member of its Technology Committee. Ms. Loewen was a member of the board of directors of Xplore Inc., a Canadian broadband service provider, and a member of its Audit Committee from 2021 to 2023. She is also a former member of the Public Sector Pension Investment Board from 2001 to 2007, where she served on the Audit and Conflicts 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 has been the Chancellor of Mount Allison University in Sackville, New Brunswick, a member of the Executive Committee and Chair of its Nominating and Governance Committee since 2018. She was a member of the Board of Regents from 1998 to 2008, serving as Chair from 20072008.
Ms. Loewen holds a Bachelor of Commerce from Mount Allison University. She is a Fellow of the Chartered Professional Accountants and has received the Directors designation from the Institute of Corporate Directors.
Ms. Loewens financial expertise and business acumen gained as a senior executive in the telecom and airline sectors are valuable assets for the Emera Board.
Board and Committee membership |
Attendance | Total | ||||||
Board |
8 of 8 | 100 | % | |||||
Audit Committee |
5 of 5 | 100 | % | |||||
Health, Safety and Environment Committee |
3 of 3 | 100 | % | |||||
Risk and Sustainability Committee |
3 of 3 | 100 | % |
Total compensation |
||||||||
Fees earned in 2023 ($) |
All other compensation ($) | Total ($) | ||||||
296,000 |
Nil | 296,000 |
DSUs awarded and held |
||||||||
2023 share-based awards ($) |
Total 2023 change in value of all DSUs held ($) |
Market value of total DSU holdings ($) |
||||||
296,000 | (78,193 | ) | 3,153,147 |
Emera Securities held |
||||||||||||
2021 | 2022 | 2023 | ||||||||||
Common shares |
4,490 | 4,490 | 4,490 | |||||||||
DSUs |
46,982 | 53,926 | 62,687 | |||||||||
Value of shares and DSUs ($) |
3,254,060 | 3,023,033 | 3,378,994 | |||||||||
Status under share ownership guideline (1) |
|
Ms. Loewen owns shares and DSUs valued at over 12.2x the value of the Annual Directors retainer; therefore, the guideline has been met. |
|
(1) | Under Emeras Director Share Ownership Guideline, a Director must own three times the total cash and equity-based annual Director retainer in Emera common shares or DSUs, or a combination of the two. For more information, see Director Share Ownership Guideline in the Corporate Governance section later in this Circular. |
EMERA INCORPORATED | 23 |
Notice of Annual Meeting of Common Shareholders and Management Information Circular
BRIAN PORTER
Director Since: 2024 | Independent Director |
Toronto, Ontario
Canada
Age: 66
Skills and Experience
| CEO/Senior Executive |
| Sustainability/ESG |
| Governance |
| Risk Management |
| Customer/Stakeholder |
| Strategic Planning, M&A or Growth Strategy |
| Talent Management and Executive Compensation |
| Financial Literacy and Accounting |
| Government Relations, Public Policy and Regulatory |
Other Public Company Boards (last five years)
| Fairfax Financial Holdings Ltd. (April 2023 to present) |
| Bank of Nova Scotia (November 2013 to January 2023) |
Mr. Porter joined the Emera Board on March 6, 2024.
Mr. Porter was the President and CEO of the Bank of Nova Scotia, operating as Scotiabank, a global bank operating in Canada and the Americas, from November 2013 until his retirement in January 2023.
Mr. Porter is Chair of the Board of Governors of Huron University College at Western University, Chair of the Ontario Infrastructure Bank and Chair of the Atlantic Salmon Board (Canada). He previously served as Chair of the University Health Network (UHN) Board of Trustees.
He is a Director of the Fairfax Financial Holdings Ltd.
Mr. Porter received a Bachelor of Commerce from Dalhousie University, and was awarded an Honorary Doctor of Laws from Dalhousie University in 2008 and from Ryerson University in 2018. He is a graduate of the Advanced Management Program of the Harvard Business School.
Mr. Porters extensive experience in banking and capital markets and as a public company executive leading one of Canadas largest chartered banks through a period of significant growth and expansion are significant assets for the Emera Board.
Board and Committee membership |
Attendance | Total | ||||||
Board (1) |
N/A | N/A |
Total compensation |
||||||||
Fees earned in 2023 ($) |
All other compensation ($) | Total ($) | ||||||
Nil |
Nil | Nil |
DSUs awarded and held |
||||||||
2023 share- awards ($) |
Total 2023 change in value of all DSUs held ($) |
Market value of total DSU holdings ($) |
||||||
Nil | Nil | Nil |
Emera Securities held |
||||||||||||
2021 | 2022 | 2023 | ||||||||||
Common shares |
Nil | Nil | 10,000 | |||||||||
DSUs |
Nil | Nil | Nil | |||||||||
Value of shares and DSUs ($) |
Nil | Nil | 503,000 | |||||||||
Status under share ownership guideline (2) |
|
Mr. Porter joined the Board in March 2024 and owns common shares valued at over 1.8x the value of the Annual Directors retainer. He has until March 2027 to meet the share ownership guideline. |
|
(1) | Mr. Porter joined the Board of Directors in March 2024 and therefore did not attend any Board or Committee meetings during 2023. |
(2) | Under Emeras Director Share Ownership Guideline, a Director must own three times the total cash and equity-based annual Director retainer in Emera common shares or DSUs, or a combination of the two. For more information, see Director Share Ownership Guideline in the Corporate Governance section later in this Circular. |
24 | EMERA INCORPORATED |
Notice of Annual Meeting of Common Shareholders and Management Information Circular
IAN ROBERTSON
Director Since: 2022 | Independent Director |
Oakville, Ontario
Canada
Age: 64
Skills and Experience
| CEO/Senior Executive |
| Sustainability/ESG |
| Governance |
| Risk Management |
| Customer/Stakeholder |
| Energy Sector or Utility Sector |
| Strategic Planning, M&A or Growth Strategy |
| Talent Management and Executive Compensation |
| Financial Literacy and Accounting |
| Government Relations, Public Policy and Regulatory |
2023 Annual Meeting Votes for: 99.65%
Other Public Company Boards
(last five years)
| Embark Technology, Inc. (November 2021 to August 2023) |
| Northern Genesis Acquisition Corp. III (March 2021 to May 2023) |
| Largo Resources Ltd. (March 2021 to July 2022) |
| Lion Electric Company (May 2021 to November 2021) |
| Northern Genesis Acquisition Corp. (August 2020 to May 2021) (1) |
| Northern Genesis Acquisition Corp. II (January 2021 to November 2021) (2) |
| Algonquin Power & Utilities Corp. (December 2009 to July 2020) |
| Atlantica Sustainable Infrastructure plc (March 2018 to April 2020) |
Mr. Robertson joined Emeras Board in February 2022. He became a member of the Audit Committee and the Risk and Sustainability Committee in May 2022.
Mr. Robertson has over 30 years of experience in the development of electric power generating projects and the operation of diversified regulated utilities. He is a principal of the Northern Genesis Capital Group, an investment group focused on identifying and acquiring energy transition businesses that demonstrate strong sustainability and environmental, social and governance alignment. He is the former CEO of Algonquin Power & Utilities Corp. (Algonquin Power), a publicly traded, diversified, international generation, transmission, and distribution utility. He was also the founder and principal of Algonquin Powers predecessor, Algonquin Power Corporation Inc., a private independent power developer formed in 1988.
Mr. Robertson is an electrical engineer and holds a Professional Engineering designation through his Bachelor of Applied Science from the University of Waterloo. He earned a Master of Business Administration from York Universitys Schulich School of Business. He holds a Chartered Financial Analyst designation, as well as a global professional Master of Laws from the University of Toronto. He received a Chartered Director designation from the Directors College of McMaster University.
During his time as CEO of Algonquin Power and its predecessor entities, Mr. Robertson led the organization through a period of extraordinary growth. His entrepreneurial approach to building a leading North American regulated utility business, focused on renewable energy, is a distinct asset to Emeras Board.
Board and Committee membership |
Attendance | Total | ||||||
Board |
8 of 8 | 100 | % | |||||
Audit Committee |
5 of 5 | 100 | % | |||||
Risk and Sustainability Committee |
3 of 3 | 100 | % |
Total compensation |
||||||||
Fees earned in 2023 ($) |
All other compensation ($) | Total ($) | ||||||
285,500 |
Nil | 285,500 |
DSUs awarded and held |
||||||||
2023 awards |
Total 2023 change in value of all DSUs held ($) |
Market value of total DSU holdings ($) |
||||||
285,500 |
(5,673 | ) | 490,772 |
Emera Securities held |
||||||||||||
2021 | 2022 | 2023 | ||||||||||
Common shares |
7,950 | 12,600 | 32,600 | |||||||||
DSUs |
Nil | 3,912 | 9,757 | |||||||||
Value of shares and DSUs ($) |
502,599 | 854,503 | 2,130,552 | |||||||||
Status under share ownership guideline (3) | |
Mr. Robertson owns shares and DSUs valued at over 7.7x the value of the Annual Directors retainer; therefore, the guideline has been met. |
|
(1) | Mr. Robertson was a member of the board of Northern Genesis Acquisition Corp. from August 2020 to May 2021 when it merged with Lion Electric Company. |
(2) | Mr. Robertson was on the board of directors of Northern Genesis Acquisition Corp. II from January 2021 to November 2021, when it merged with Embark Technology, Inc. |
(3) | Under Emeras Director Share Ownership Guideline, a Director must own three times the total cash and equity-based annual Director retainer in Emera common shares or DSUs, or a combination of the two. For more information, see Director Share Ownership Guideline in the Corporate Governance section later in this Circular. |
EMERA INCORPORATED | 25 |
Notice of Annual Meeting of Common Shareholders and Management Information Circular
JACKIE SHEPPARD
Director Since: 2009 | Independent Director |
Calgary, Alberta
Canada
Age: 68
Skills and Experience
| CEO/Senior Executive |
| Sustainability/ESG |
| Governance |
| Risk Management |
| Customer/Stakeholder |
| Energy Sector or Utility Sector |
| Strategic Planning, M&A or Growth Strategy |
| Talent Management and Executive Compensation |
| Financial Literacy and Accounting |
| Government Relations, Public Policy and Regulatory |
2023 Annual Meeting Votes for: 99.11%
Other Public Company Boards
(last five years)
| Suncor Energy Inc. (July 2022 to present) |
| ARC Resources Ltd. (March 2021 to present) |
| Seven Generations Energy Ltd. (May 2016 to March 2021) (1) |
Ms. Sheppard has been a Director of Emera 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 is a former Director of Emeras 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 corporate director and currently sits on the boards of Suncor Energy Inc., a Canadian integrated energy company, and ARC Resources Ltd., a publicly traded Canadian energy company. She was founder and Lead Director of Black Swan Energy Inc., an Alberta upstream energy company that was sold in July 2021. She is a former Director of Cairn Energy PLC, a publicly traded UK-based international upstream company, and the Alberta Investment Management Corporation (AIMCo), an institutional investment manager, as well as a former director of the general partner of Pacific Northwest LNG LP. She also 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. She earned a Bachelor of Laws (Honours) from McGill University and a Bachelor of Arts from Memorial University of Newfoundland. She was awarded an honorary Doctor of Laws from Memorial University in 2019. In 2008, Ms. Sheppard was appointed the Kings Counsel designation and in 2023 became a Fellow of the Institute of Corporate Directors, Canadas preeminent distinction for directors.
With her extensive experience as an executive in the energy industry, and as a director of public, private and Crown corporations, Ms. Sheppards expertise in strategic planning, business development, public markets, legal and governance is of significant value to Emeras Board.
Board and Committee membership |
Attendance | Total | ||||||
Board (Chair) (2) |
8 of 8 | 100 | % |
Total compensation |
||||||||
Fees earned in 2023 ($) |
All other compensation ($) | Total ($) | ||||||
460,000 |
N/A | 460,000 |
DSUs awarded and held |
||||||||
2023 awards |
Total 2023 change in value of all DSUs held ($) |
Market value of total DSU holdings ($) |
||||||
460,000 |
(166,636 | ) | 6,550,132 |
Emera Securities held |
||||||||||||
2021 | 2022 | 2023 | ||||||||||
Common shares |
11,947 | 11,947 | 11,947 | |||||||||
DSUs |
102,707 | 114,921 | 130,221 | |||||||||
Value of shares and DSUs ($) |
7,248,426 | 6,565,436 | 7,151,066 | |||||||||
Status under share ownership guideline (3) | |
Ms. Sheppard owns shares and DSUs valued at over 15x the value of the Annual Chairs retainer; therefore, the guideline has been met. |
|
(1) | Ms. Sheppard was a member of the Board of Seven Generations Energy Ltd. from May 2016 until March 31, 2021, when it merged with ARC Resources Ltd. |
(2) | Ms. Sheppard attended all Committee meetings in 2023 in her capacity as Chair of the Board. |
(3) | Under Emeras Director Share Ownership Guideline, a Director must own three times the total cash and equity-based annual Director retainer in Emera common shares or DSUs, or a combination of the two. For more information, see Director Share Ownership Guideline in the Corporate Governance section later in this Circular. |
26 | EMERA INCORPORATED |
Notice of Annual Meeting of Common Shareholders and Management Information Circular
KAREN SHERIFF
Director Since: 2021 | Independent Director |
Picton, Ontario
Canada
Age: 66
Skills and Experience
| CEO/Senior Executive |
| Sustainability/ESG |
| Governance |
| Risk Management |
| Customer/Stakeholder |
| Energy Sector or Utility Sector |
| Strategic Planning, M&A or Growth Strategy |
| Talent Management and Executive Compensation |
| Financial Literacy and Accounting |
| Government Relations, Public Policy and Regulatory |
2023 Annual Meeting Votes for: 99.42%
Other Public Company Boards
(last five years)
| BCE Inc. (April 2017 to present) |
| WestJet Airlines Ltd. (January 2016 to December 2019) |
Ms. Sheriff joined Emeras Board in February 2021. She became a member of the Management Resources and Compensation Committee in May 2021 and a member of the Risk and Sustainability Committee in September 2021. She became a member of the Nominating and Corporate Governance Committee in May 2023.
Ms. Sheriff is a corporate director and the former President and CEO of Q9 Networks Inc., a data centre services provider. From 2008 to 2014, she was President and CEO of Bell Aliant, Inc., a telecommunications company. She was in senior leadership positions for more than nine years with BCE Inc. and currently serves on the Board of Directors of BCE Inc. She also spent over 10 years at United Airlines in the areas of marketing, strategy, human resources, and finance.
Ms. Sheriff is a former member of the boards of CPP Investments and WestJet Airlines Ltd. Ms. Sheriff received her master of Business Administration with concentrations in marketing and finance from the University of Chicago. She was named one of Canadas top 25 Women of Influence for 2013 and 2014 by Women of Influence Inc. and named Woman of the Year by Canadian Women in Communications. She has been recognized as one of Atlantic Canadas Top 50 CEOs by Atlantic Business Magazine and one of Canadas Top 100 Most Powerful Women on multiple occasions.
With her extensive senior executive experience, including as CEO of a public company and as a leader in the transformation of Bell Aliant, Ms. Sheriff brings 20 years of technology- based industry experience. Along with this, her experience in leading a regulated utility and her involvement in significant mergers and acquisitions, including Bell Aliant, Q9, CTV and the sale of WestJet to Onex, make Ms. Sheriff a valuable member of Emeras Board.
Board and Committee membership |
Attendance | Total | ||||||
Board |
8 of 8 | 100 | % | |||||
Management Resources and Compensation Committee |
6 of 6 | 100 | % | |||||
Risk and Sustainability Committee |
3 of 3 | 100 | % | |||||
Nominating and Corporate Governance Committee (1) |
4 of 4 | 100 | % |
Total compensation |
||||||||
Fees earned in 2023 ($) |
All other compensation ($) | Total ($) | ||||||
286,779 |
Nil | 286,779 |
DSUs awarded and held |
||||||||
2023 awards |
Total 2023 change in value of all DSUs held ($) |
Market value of total DSU holdings ($) |
||||||
286,779 |
(13,212 | ) | 767,729 |
Emera Securities held |
||||||||||||
2021 | 2022 | 2023 | ||||||||||
Common shares |
1,000 | 1,000 | 1,000 | |||||||||
DSUs |
4,379 | 9,112 | 15,263 | |||||||||
Value of shares and DSUs ($) |
340,060 | 523,285 | 818,029 | |||||||||
Status under share ownership guideline (2) | |
Ms. Sheriff owns shares and DSUs valued at over 2.9x the value of the Annual Directors retainer. She has until February 2026 to meet the guideline. |
|
(1) | Ms. Sheriff was appointed a member of the Nominating and Corporate Governance Committee on May 24, 2023 and has attended all meetings of this Committee since being appointed. |
(2) | Under Emeras Director Share Ownership Guideline, a Director must own three times the total cash and equity-based annual Director retainer in Emera common shares or DSUs, or a combination of the two. For more information, see Director Share Ownership Guideline in the Corporate Governance section later in this Circular. |
EMERA INCORPORATED | 27 |
Notice of Annual Meeting of Common Shareholders and Management Information Circular
JOCHEN TILK
Director Since: 2018 | Independent Director |
Toronto, Ontario
Canada
Age: 60
Skills and Experience
| CEO/Senior Executive |
| Sustainability/ESG |
| Governance |
| Risk Management |
| Strategic Planning, M&A or Growth Strategy |
| Talent Management and Executive Compensation |
2023 Annual Meeting Votes for: 99.05%
Other Public Company Boards
(last five years)
| AngloGold Ashanti Plc (January 2019 to present) |
Mr. Tilk has been a Director of Emera since July 2018. He became a member of the Management Resources and Compensation Committee in May 2019 and the Nominating and Corporate Governance Committee in May 2021. He was appointed Chair of the newly established Risk and Sustainability Committee in September 2021, and served as a member of the Audit Committee from November 2018 until May 2021.
Mr. Tilk is the former Executive Chair of Nutrien Ltd., a Canadian global supplier of agricultural products and services based in Saskatoon, Saskatchewan. He is the former President and CEO 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 companys President and CEO.
Mr. Tilk is a corporate director and currently serves on the board of AngloGold Ashanti Plc, a publicly listed international gold mining company based in London, UK. He is also Vice-Chair of the Princess Margaret Cancer Foundation, a not-for-profit organization in Toronto, Ontario. He is the former Chair of the Board of Canpotex Limited, a Canadian potash exporter, and a former Director of the Fertilizer Institute, a United States-based industry organization. He is also a former director of the International Fertilizer Association.
Mr. Tilk received his master in mining engineering from Rheinisch-Westfälische Technische Hochschule, a research university located in Aachen, North Rhine-Westphalia, Germany.
Mr. Tilks track record of growing companies and leading multi-billion-dollar capital expenditure programs makes him an important contributor to Emeras Board.
Board and Committee membership |
Attendance | Total | ||||||
Board |
8 of 8 | 100 | % | |||||
Risk and Sustainability Committee (Chair) |
3 of 3 | 100 | % | |||||
Management Resources and Compensation Committee |
6 of 6 | 100 | % | |||||
Nominating and Corporate Governance Committee |
6 of 6 | 100 | % |
Total compensation |
||||||||
Fees earned in 2023 ($) |
All other compensation ($) | Total ($) | ||||||
306,000 |
Nil | 306,000 |
DSUs awarded and held |
||||||||
2023 share- awards ($) |
Total 2023 change in value of all DSUs held ($) |
Market value of total DSU holdings ($) |
||||||
306,000 |
(32,177 | ) | 1,480,356 |
Emera Securities held |
||||||||||||
2021 | 2022 | 2023 | ||||||||||
Common shares |
Nil | Nil | Nil | |||||||||
DSUs |
16,523 | 22,191 | 29,431 | |||||||||
Value of shares and DSUs ($) |
1,044,584 | 1,148,399 | 1,480,356 | |||||||||
Status under share ownership guideline (1) | |
Mr. Tilk owns DSUs valued at over 5.3x the value of the annual Director retainer; therefore, the guideline has been met. |
|
(1) | Under Emeras Director Share Ownership Guideline, a Director must own three times the total cash and equity-based annual Director retainer in Emera common shares or DSUs, or a combination of the two. For more information, see Director Share Ownership Guideline in the Corporate Governance section later in this Circular. |
28 | EMERA INCORPORATED |
Notice of Annual Meeting of Common Shareholders and Management Information Circular
1.4 | Additional Information |
2023 BOARD AND COMMITTEE MEETING ATTENDANCE
The total number of Board and Committee Meetings held in 2023 with overall Director attendance is summarized in the table and graph below.
Type of meeting |
Number of meetings |
Overall attendance |
||||||
Board |
8 | 99 | % | |||||
Audit Committee |
5 | 100 | % | |||||
Health, Safety and Environment Committee |
3 | 100 | % | |||||
Management Resources and Compensation Committee |
6 | 100 | % | |||||
Nominating and Corporate Governance Committee |
6 | 100 | % | |||||
Risk and Sustainability Committee |
3 | 100 | % | |||||
|
|
|||||||
Total meetings: |
31 | |||||||
|
|
DIRECTOR NOMINEE SKILLS AND EXPERIENCE
The following table shows the skills and experience of each Director nominee in areas identified as necessary for effective oversight of Emera given its current operations and strategy. These qualifications are considered in reviewing Board succession and recruiting new Board members.
Name of Director Nominees |
CEO/Senior Executive |
Sustainability /ESG |
Governance | Risk Management |
Customer/ Stakeholder |
Energy Sector or Utility Sector |
Strategic Planning, M&A or Growth Strategy |
Talent Management and Executive Compensation |
Financial Literacy and Accounting |
Government Relations, Public Policy and Regulatory | ||||||||||
Scott Balfour |
✓ | ✓ | ✓ | ✓ | ✓ | ✓ | ✓ | ✓ | ✓ | ✓ | ||||||||||
James Bertram |
✓ | ✓ | ✓ | ✓ | ✓ | ✓ | ✓ | |||||||||||||
Henry Demone |
✓ | ✓ | ✓ | ✓ | ✓ | ✓ | ||||||||||||||
Paula Gold-Williams |
✓ | ✓ | ✓ | ✓ | ✓ | ✓ | ✓ | ✓ | ✓ | ✓ | ||||||||||
Kent Harvey |
✓ | ✓ | ✓ | ✓ | ✓ | ✓ | ✓ | |||||||||||||
Lynn Loewen |
✓ | ✓ | ✓ | ✓ | ✓ | ✓ | ✓ | ✓ | ✓ | |||||||||||
Brian Porter |
✓ | ✓ | ✓ | ✓ | ✓ | ✓ | ✓ | ✓ | ✓ | |||||||||||
Ian Robertson |
✓ | ✓ | ✓ | ✓ | ✓ | ✓ | ✓ | ✓ | ✓ | ✓ | ||||||||||
Jackie Sheppard |
✓ | ✓ | ✓ | ✓ | ✓ | ✓ | ✓ | ✓ | ✓ | ✓ | ||||||||||
Karen Sheriff |
✓ | ✓ | ✓ | ✓ | ✓ | ✓ | ✓ | ✓ | ✓ | ✓ | ||||||||||
Jochen Tilk |
✓ | ✓ | ✓ | ✓ | ✓ | ✓ | ||||||||||||||
|
|
|
|
|
|
|
|
|
| |||||||||||
Total Number of Directors with Skills |
11 | 10 | 11 | 9 | 9 | 7 | 11 | 10 | 8 | 8 | ||||||||||
|
|
|
|
|
|
|
|
|
|
EMERA INCORPORATED | 29 |
Notice of Annual Meeting of Common Shareholders and Management Information Circular
Description of Skills and Experience
CEO/Senior Executive CEO or senior executive experience with a large organization.
Sustainability/ESG Experience as a senior executive leading, or as a director with oversight responsibilities for, a significant number of environmental, social and governance programs, sustainable practices and policies (including those in relation to climate risk), corporate social responsibility programs and/or diversity, equity and inclusion initiatives.
Governance Experience with corporate governance practices and principles at a major organization.
Risk Management Experience overseeing the various risks facing an organization, with oversight of appropriate policies and procedures to effectively manage risk.
Customer/Stakeholder Experience as a senior executive in a customer-centric product or service company.
Energy Sector or Utility Sector Has been a senior executive of a public utility or energy company.
Strategic Planning, M&A or Growth Strategy Experience defining and driving strategic direction and growth, including leading complex merger and acquisitions (M&A) transactions, or leading the growth or transformation of a company.
Talent Management and Executive Compensation Experience in oversight of executive compensation and incentive- based compensation programs. Experience with talent recruitment and management, workplace culture, equity, diversity and inclusion, succession planning, leadership development, executive recruitment, management of organized labour in a large operating company.
Financial Literacy and Accounting Experience in corporate finance, overseeing complex financial transactions; experience in financial accounting and reporting, auditing, and internal controls.
Government Relations, Public Policy and Regulatory Experience in the workings of government and public policy in Canada or the United States, and/or experience within a public or major private corporation with complex legal and regulatory regimes in Canada or the United States.
MAJORITY VOTING FOR ELECTION OF DIRECTORS
The confidence of shareholders in the actions of the Board and management is important. In order to provide a mechanism for shareholders to express that confidence in each Director and in compliance with Subsection 461.3 of the TSX Company Manual, the Board has adopted a Majority Voting Policy for Directors.
Majority Voting Policy
Should a Director nominee, in an uncontested election at a meeting of shareholders of Emera Inc. at which Directors are to be elected, receive a majority of withheld votes from his or her election as a Director (a Majority Withheld Vote), the individual shall submit his or her resignation to the Board for consideration immediately following such shareholders meeting.
The votes determining a Majority Withheld Vote shall be the total votes cast by ballot by shareholders and proxyholders, or if a ballot vote was not conducted, shall be the total votes represented by proxies validly deposited prior to the shareholders meeting.
The Directors who received a majority For vote at the shareholders meeting shall consider whether or not to accept the resignation.
If there are less than three such Directors, the entire Board shall meet to consider the appropriate actions to be taken. The resignation of a Director who received a Majority Withheld Vote shall be accepted absent exceptional circumstances and is effective when accepted by the Directors. The determination shall be made within 90 days following the date of the shareholders meeting and a news release disclosing such determination shall be issued promptly following such determination. If the resignation is rejected, the news release shall include the reasons for rejecting the resignation. A copy of the press release shall be provided to the Toronto Stock Exchange.
Since the adoption of the Majority Voting Policy in 2008, all Director nominees have received a majority FOR vote at the Companys meetings of shareholders.
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2023 ANNUAL MEETING VOTING RESULTS
The following table provides the voting results for each item of business at the 2023 Annual Meeting on May 24, 2023 voted on by the common shareholders of the Company, being the only class of shares allowed to vote.
98% was the average vote in favour of our Director Nominees at the 2023 Annual Meeting.
Number of Votes | Percentage of Votes Cast | |||||||||||||||||||||||||||
Resolutions |
For | Against | Withheld | Total | For | Against | Withheld | |||||||||||||||||||||
1. ELECTION OF DIRECTORS: |
||||||||||||||||||||||||||||
Scott C. Balfour |
126,113,586 | 348,073 | 126,461,659 | 99.72 | % | 0.28 | % | |||||||||||||||||||||
James V. Bertram |
125,800,820 | 660,839 | 126,461,659 | 99.48 | % | 0.52 | % | |||||||||||||||||||||
Henry E. Demone |
121,382,512 | 5,079,147 | 126,461,659 | 95.98 | % | 4.02 | % | |||||||||||||||||||||
Paula Y. Gold-Williams |
125,895,546 | 566,113 | 126,461,659 | 99.55 | % | 0.45 | % | |||||||||||||||||||||
Kent M. Harvey |
125,506,742 | 954,917 | 126,461,659 | 99.24 | % | 0.76 | % | |||||||||||||||||||||
B. Lynn Loewen |
125,916,889 | 544,770 | 126,461,659 | 99.57 | % | 0.43 | % | |||||||||||||||||||||
Ian E. Robertson |
126,020,644 | 441,015 | 126,461,659 | 99.65 | % | 0.35 | % | |||||||||||||||||||||
Andrea S. Rosen |
114,345,383 | 12,116,276 | 126,461,659 | 90.42 | % | 9.58 | % | |||||||||||||||||||||
M. Jacqueline Sheppard |
125,338,192 | 1,123,467 | 126,461,659 | 99.11 | % | 0.89 | % | |||||||||||||||||||||
Karen H. Sheriff |
125,733,316 | 728,343 | 126,461,659 | 99.42 | % | 0.58 | % | |||||||||||||||||||||
Jochen E. Tilk |
125,263,299 | 1,198,360 | 126,461,659 | 99.05 | % | 0.95 | % | |||||||||||||||||||||
2. APPOINTMENT OF ERNST & YOUNG LLP AS AUDITORS |
108,697,775 | 18,443,759 | 127,141,534 | 85.49 | % | 14.51 | % | |||||||||||||||||||||
3. DIRECTORS TO ESTABLISH AUDITORS FEE |
122,214,744 | 4,245,431 | 126,460,175 | 96.64 | % | 3.36 | % | |||||||||||||||||||||
4. ADVISORY RESOLUTION ON EXECUTIVE COMPENSATION |
119,452,487 | 7,007,988 | 126,460,475 | 94.46 | % | 5.54 | % | |||||||||||||||||||||
5. STOCK OPTION PLAN |
120,852,667 | 5,607,808 | 126,460,475 | 95.57 | % | 4.43 | % | |||||||||||||||||||||
VOTES AVAILABLE |
271,424,515 | |||||||||||||||||||||||||||
VOTES RECEIVED |
127,141,534 |
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, CEO or CFO 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, CEO or CFO; 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, CEO or CFO; |
(b) | Are, as at the date of this Circular, or have been within 10 years before the date of this Circular, a director or executive officer of a company that, while that person was acting in that capacity, or within a year of that person ceasing to act in that capacity, became bankrupt, made a proposal under any legislation relating to bankruptcy or insolvency or was subject to or instituted any proceedings, arrangements or compromise with creditors or had a receiver, receiver manager or trustee appointed to hold its assets; or |
(c) | Have, within the 10 years before the date of this Circular, become bankrupt, made a proposal under any legislation relating to bankruptcy or insolvency, or become subject to or instituted any proceedings, arrangement or compromise with creditors, or had a receiver, receiver manager or trustee appointed to hold the assets of the proposed nominee. |
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2. | Corporate Governance |
Emera is committed to strong corporate governance. We review our approach to corporate governance annually and monitor best practices to help ensure we are continually enhancing our practices to create and preserve long-term shareholder value.
IN THIS SECTION | 2.1 CORPORATE GOVERNANCE PRACTICES |
33 | ||
2.2 BOARD OF DIRECTORS ABOUT THE BOARD |
34 | |||
2.3 STRATEGIC OVERSIGHT |
43 | |||
2.4 RISK MANAGEMENT |
49 | |||
2.5 ETHICAL BUSINESS CONDUCT |
50 | |||
2.6 TRANSPARENCY AND DISCLOSURE |
51 | |||
2.7 COMMITTEES OF THE BOARD OF DIRECTORS |
53 | |||
2.8 DIRECTOR COMPENSATION |
60 | |||
2.9 ADDITIONAL INFORMATION |
64 |
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2.1 | Corporate Governance Practices |
Emeras commitment to strong governance forms the foundation of our business and our commitment to shareholders. The Board annually reviews its approach to corporate governance. It monitors governance best practices, emerging trends of proxy advisors and other sources of governance thought leadership with a view to aligning Emeras strategy with its governance practices to create and preserve long-term shareholder value.
HIGHLIGHTS OF EMERAS CORPORATE GOVERNANCE PRACTICES
| Director Independence. All Emera Directors are independent from management except Emeras President and CEO. |
| Board and Committee Leadership. The Charter of the Chair of the Board and position descriptions for Committee Chairs describe the roles and responsibilities for these leadership positions. |
| Separation of Chief Executive Officer and Board Chair. |
| Independent Directors meet without Management. The Board and each Committee hold an in-camera session at each meeting that excludes management, including the CEO. |
| Director Recruitment. Directors are recruited on the basis that they will make a strong contribution and have the background, diversity, skills and experience needed in light of the Companys strategy and long-term business plans. |
| Board Renewal. The Board oversees the processes and mechanisms for renewal of the Board, which include a robust Director recruitment process, established internal governance practices, an annual Board and Director performance assessment process and consideration of established renewal principles. |
| Robust Board and Director Performance Assessments Process. The Board annually assesses its performance and that of its Chair, individual Directors and Board Committees in an effort to continuously improve its performance. |
| Board Diversity. The Board has a Board Diversity Policy which sets out a framework for promoting diversity on the Board. The Board endeavours to ensure that women and men each comprise no less than 40 per cent of the independent Directors and that the benefits of diversity are considered when identifying and considering qualified nominees for the Board. |
| Director Orientation. In-depth orientation to the Board and the Company to allow new Directors to efficiently and effectively step into their role. |
| Ongoing Director Education. Directors participate in training and education on special topics of focus or interest and regular site visits are organized to operating facilities and offices. Directors are also encouraged to pursue education opportunities of relevance to the Company to familiarize themselves with the Companys business, investments and key personnel. |
| Board Oversight of environmental, social and governance (ESG) matters, including climate issues. In 2021, the Board established the Risk and Sustainability Committee whose mandate includes responsibility for overseeing the Companys approach to sustainability and its performance relative to its sustainability objectives. |
| Rigorous Risk Management Process. The Board oversees the Companys risk management framework and risk management with the support of the Boards Risk and Sustainability Committee. |
| Strong Cybersecurity Oversight. Cybersecurity risk is overseen by the Board, with a report provided to the Risk and Sustainability Committee on a quarterly basis. |
| Committees of the Board. Five 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, the Risk and Sustainability Committee and the Health, Safety and Environment Committee. Ad hoc special committees are struck from time to time as needed for specific matters. |
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| Share Ownership Requirement. A Director must own a minimum of three times (3x) the total cash and equity-based annual Board retainer in Emera common shares or DSUs, or a combination of the two. |
| Culture of Integrity. Directors, Officers and employees are required to annually acknowledge that they have reviewed and understand the Emera Code of Conduct, which is overseen by the Nominating and Corporate Governance Committee. |
| Shareholder Engagement. Shareholders can communicate directly with the Chair of the Board or other independent Directors through private and confidential correspondence. |
OPERATING COMPANY GOVERNANCE
Emeras operating companies also have robust and disciplined governance processes that align to reflect Emeras governance principles. In our largest operating companies, external, independent and local Directors are added to the operating company Board until they form a majority on the Board. Local Directors bring additional connection to the community where the business is located.
The Chair of each operating company Board is elected in accordance with the operating companys organizational documents and is typically Emeras CEO or an Emera executive based on the CEOs recommendation. Additional Emera and operating company executives may also be Directors but, combined, would typically form a minority of the Board. Emeras operating companies seek to achieve and maintain a Board comprised of talented and dedicated Directors with a diverse mix of experience, skills and backgrounds.
As the parent company, Emera provides certain corporate-wide services to its operating companies. These include safety, environment, compliance, internal audit, insurance, corporate security and treasury services. Enterprise-wide policies such as Emeras safety management system are either expressly adopted by an operating company Board, or the impact is considered by Emera through consultation with the operating company, which may result in operating company-specific adjustments.
2.2 | Board of Directors About the Board |
BOARD OF DIRECTORS CHARTER
The Emera Board is responsible for overseeing the management of the business of the Company and for providing stewardship and governance for its long-term success.
The Board of Directors Charter (included in Appendix A) is reviewed annually and sets out the duties and responsibilities of the Board in the areas of:
| Strategic Planning |
| Culture |
| Risk |
| Leadership and Succession |
| Financial Performance |
| Corporate Communications and Public Disclosure |
| Governance Responsibility |
BOARD COMMITTEES
The Board of Directors has the following five standing Committees to assist it in carrying out its duties.
1. | Audit Committee; |
2. | Management Resources and Compensation Committee (MRCC); |
3. | Nominating and Corporate Governance Committee (NCGC); |
4. | Health, Safety and Environment Committee (HSEC); and |
5. | Risk and Sustainability Committee (RSC). |
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From time to time, the Board may establish ad hoc committees to assist the Board on specific matters of a temporary nature. For the full text of the Audit Committee, MRCC, NCGC, HSEC, and RSC Charters, visit www.emera.com/governance.
The NCGC is responsible for assisting the Board and its Committees in determining Committee composition.
Board members who may not be members of a Committee are extended an ongoing invitation to sit in on Committee meetings to experience first-hand the operations of other Committees and allow easier rotation of membership by increasing the familiarity of non-Committee members with the activities of the various Committees.
Please see the section entitled Committees of the Board of Directors later in this Circular for more information about the activities of the Committees in 2023.
DIRECTOR AND CHAIR INDEPENDENCE
Ms. Sheppard, the Chair of the Board, is an independent Director. The Articles of Association of the Company (Articles) require that the Chair of the Board and the President and CEO be separate individuals. The Chair of the Board may not be an employee of the Company or of any subsidiary or affiliate of the Company.
All Emera Directors are independent from management, except for Mr. Balfour, who is President and CEO of Emera. All of the Board Committees must be comprised entirely of independent Directors, except for the HSEC and the RSC, which are required to be majority independent.
Use of the term independent in relation to a Director 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 Directors independent judgement.
Except for Mr. Harvey, who receives a retainer for being a member of the Board of Emeras subsidiary, Emera US Holdings Inc., (1) Directors receive no other remuneration from Emera other than Directors retainers, fees or retainers for service as a Director or Chair of the Board or Chair or member of a Committee, and an annual travel allowance. Ms. Sheppard receives an all-inclusive annual retainer as Chair of the Board of Emera. As noted later in this Circular under the section Total Director Compensation in 2023, 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 Emeras subsidiaries or investments, beyond his compensation as Emeras President and CEO.
The Articles provide that no more than two Directors may be employees of the Company or one of its operating companies. Mr. Balfour is the only Director employed by the Company or any of its operating companies.
POSITION DESCRIPTIONS
Chair of the Board
The Chair provides leadership to the Board, in order that it may fulfil its duties effectively, efficiently and independent of management. The Chairs role is to ensure the Board and shareholder meetings function effectively. The Chair leads Board discussions and represents the Board in providing additional advice and counsel to the President and CEO, and senior leadership. At the request of the President and CEO, or where appropriate, the Chair of the Board also represents the Board at official functions and meetings with major shareholders and other stakeholder groups.
The Chair oversees and monitors the work of the Board Committees to ensure that delegated Committee functions are carried out and reported to the Board. The Chair of the Board attends all Committee meetings in his or her capacity as Board Chair.
Under the leadership of the NCGC, the Chair participates in the recruitment and retention of Directors and oversees appropriate processes to determine that the Board of Directors has the requisite skill sets needed for effective oversight of the Company given its operations and strategy. The Chair also leads an annual assessment of the effectiveness of the overall Board and its members.
The Board has adopted a Chair of the Board of Directors Charter which delineates the role of the Chair and their responsibilities. A copy of the Chair of the Board of Directors Charter can be found at www.emera.com/governance.
(1) | Mr. Rick Sergel was a Director of Emera US Holdings Inc. until his resignation on May 24, 2023 (concurrent with him ceasing to be a Director of Emera at our 2023 Annual Meeting). Mr. Harvey became a Director of Emera US Holdings Inc. effective May 24, 2023. Please see Total Director Compensation in 2023 later in this Circular. |
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Committee Chairs
The Board has adopted written 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 Committees effective fulfilment of its mandate. The position descriptions for each Committee Chair can be found at www.emera.com/governance.
President and Chief Executive Officer
The President and CEO is responsible for leadership of the Company and its employees. He or she is responsible for defining, communicating and implementing the direction, goals and core values of the Company, including:
| Leading the development of Emeras vision and strategic plans; |
| Delivering Emeras financial performance; and |
| Developing senior leadership succession planning and development as detailed in the Succession Planning and Leadership Development section found later in this Circular. |
The roles and responsibilities of the President and CEO are contained in his or her employment contract. The President and CEOs employment contract is reviewed by the Chair of the Board and the MRCC, and is approved by the Board of Directors.
Among the various responsibilities of the Board, CEO selection is of critical importance. The MRCC assists the Board in the succession planning process in respect of the President and CEO. For more information about the succession planning process for the President and CEO see the section entitled Succession Planning and Leadership Development later in this Circular.
BOARD AND COMMITTEE MEETINGS
There were 31 Emera Board and Committee meetings during 2023. See the section entitled 2023 Board and Committee Meeting Attendance for more detailed information.
The Board and each Committee have adopted the practice of, at each meeting, holding an in-camera session, during which the President and CEO and all other members of management are excluded. The Board sessions are presided over by the Companys independent Board Chair. The Committee sessions are presided over by the independent Chairs of the respective Committees. In 2023, the Board and each Committee held an in-camera session at each meeting of the Board and each Committee meeting.
The Board generally holds an evening session before each regularly scheduled Board meeting and prior to the Boards annual strategy meeting. As a governance practice, at least once a year, the independent Directors conduct such a session that excludes the President and CEO and all other management.
DIRECTORS OCCUPATION
The Directors have also instituted a policy that requires them to submit their resignation as a Director if there is a significant change in their principal occupation. The resignation is then considered by the Board, which determines if the change in the Directors circumstances warrant acceptance of the resignation, whether due to a conflict of interest arising by virtue of a new principal occupation or otherwise.
DIRECTORS MEMBERSHIP ON OTHER PUBLIC COMPANY BOARDS
Public company board membership for each Director nominee during the last five years is included in their profiles in the section entitled Director Nominees. Current Director Andrea Rosen, who is retiring from the Board and is not standing for re-election, serves on the Board of Directors of Element Fleet Management Corp., Ceridian HCM Holding Inc. and Manulife Financial Corporation.
In 2023, the Board, on the recommendation of the NCGC, amended the Companys corporate governance practices to provide that Directors must notify and obtain the approval of the Chair of the Board prior to accepting a position on the board of another company.
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BOARD INTERLOCKS
An interlock occurs when two or more of Emera Directors are on the board of another public company. There are currently no Emera Directors who sit on the board of another public company with one or more other Emera Directors.
BOARD SIZE
The Articles provide that the number of Directors on the Companys Board must not be less than eight and not more than 15. Eleven Director nominees are being proposed for election at the 2024 Annual Meeting.
NOMINATION OF DIRECTORS AND DIRECTOR RECRUITMENT PROCESS
The NCGC is responsible for providing the Company with a list of Director nominees for election at the Companys Annual Meeting. The NCGC develops a list of nominees after carefully considering the mix of skills and experience of its Directors and the feedback received through the Board Assessment. The NCGC also evaluates the size of the Board, and its diversity having regard to the Board Diversity Policy. This includes considering the level of representation of women and men on the Board and other diversity characteristics. In accordance with the Board Diversity Policy, when identifying and considering the selection of qualified Director nominees, the NCGC endeavours to ensure that women and men each comprise no less than 40 per cent of the independent directors.
To support the Boards diversity objectives outlined in the Board Diversity Policy, during the process of identifying and considering the selection of qualified nominees for the Board, the NCGC will include active consideration of candidates on the basis of Indigenous heritage, racial status, disability or other diversity characteristics. See the section entitled Board Diversity for more information about Emeras Board Diversity Policy.
Director nominees must, in the opinion of the members of the NCGC, be able to fully discharge their duties as Directors and contribute to the broad range of issues that 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 evaluates the expected turnover of Directors in advance of their retirement from the Board and develops an effective succession plan.
Working with the Board Chair, the NCGC considers recruitment in the context of the age and tenure of current members and considers the Boards overall policy of ensuring renewal and orderly Board succession. For more information about the average age and tenure of Emeras Director nominees for the Companys 2024 Annual Meeting, refer to the section below entitled Board Renewal.
The NCGC also considers the potential tenure of a Director candidate before making a selection.
BOARD RENEWAL
The Board oversees processes for renewal of the Board, which balance many factors, and have as their ultimate objective the fulfilment of the fundamental responsibility of the Board to provide stewardship and good governance for the Company. Those processes address Board renewal in a deliberate manner and primarily include: a robust Director recruitment process, internal governance practices that regularly assess each of the Boards desired skills, and the conduct of an annual performance assessment of the Board, its Committees and individual Board members.
While Emera has no formal term or age limits for its Directors, absent certain circumstances as determined by the Board, in the normal course, a Director who would be 72 years of age at the Annual Meeting would not be nominated, nor would a Director who has served as a Director for more than 15 years, in accordance with the Guideline on Board Tenure.
Emeras governance practices include that planned departures of Board members in any one year will not exceed two Directors. This practice supports both Board renewal and continuity.
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Board Renewal Principles
When recommending the nomination of Directors for election, the NCGC members must consider certain principles:
Board renewal principle |
Principle explained | |
Age | As Directors approach 70 years of age, the NCGC assesses the needs of the Board, based on the Boards complement and other relevant factors. Where a determination is made that such Director will be retiring, the NCGC begins the replacement process. | |
Tenure | The length of time that a nominee has served on the Companys Board of Directors is considered, subject to the Guideline on Board Tenure which established a general Director tenure guideline of 15 years, with a view to the Board having Directors with an appropriate mix of tenures. | |
Average age | The average age of all of the Companys Director nominees is determined and considered. | |
Average tenure | The average tenure of all of the Companys Director nominees is determined and considered. | |
Other relevant factors | The NCGC considers any other factor Committee members determine to be relevant in the promotion of orderly succession and balanced renewal of membership on the Board, having as its ultimate objective the constitution of a Board of Directors that fulfils the fundamental responsibility of providing stewardship and good governance for the Company. |
Application of Board Renewal Principles
The NCGC applied the Board renewal principles to the Director nominees for Emeras 2024 Annual Meeting. In addition to the other Board renewal principles, the Committee considered the average age and average tenure of all the Companys Director nominees for election at the 2024 Annual Meeting, as represented by the diagrams below.
By comparison, the average age and average tenure of Directors in prior years was as follows:
Renewal principle |
2021 | 2022 | 2023 | |||||||||
Average age |
64.35 years | 64.07 years | 64.23 years | |||||||||
Average tenure |
6.68 years | 6.26 years | 6.80 years |
In applying the Board Renewal Principles as described, the NCGC has recommended to the Board of Directors all of the 11 Director nominees presented earlier in this Circular under the Director Nominees section. The Board is confident that this an appropriate size for the Board to fulfil its mandate, to ensure the committees have the appropriate leadership and skills and to facilitate board renewal.
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GUIDELINE ON BOARD TENURE | ||
In applying the guideline of 15 years when considering re-nominations for Directors, the NCGC shall take into consideration the needs of the Board at the time, the best interests of Emera given its strategic objectives, orderly succession and the results of the annual Board and Director performance assessment. | ||
As of the date of Emeras 2024 Annual Meeting, all but one of the Director nominees will have served on the Board for less than 15 years. | Jackie Sheppard joined the Emera Board in February 2009, and has served as Chair of the Board since May 2014, joining Emera just over 15 years ago. Although her tenure exceeds the Board Tenure Guideline, the Board has determined that she be re-nominated for election as a Director on the recommendation of the NCGC. The NCGC and the Board considered a number of factors, including Ms. Sheppards extensive executive experience in the energy industry, as well as her expertise in strategic planning, public markets, legal and corporate governance. Board members determined that she remains a completely independent member of the Board who rigorously holds management to account. The NCGC and the Board also determined that Ms. Sheppard provides important continuity on the Board given the upcoming departure of Andrea Rosen from the Board and the previous retirement of Mr. Sergel in 2023, as well as the integration of new Board members. Her nomination will allow for a smooth transition in light of these retirements and balances the desire for renewal with the need for stability and continuity. To help ensure the continued renewal of the Board, Mr. Porter was appointed in March 2024. |
BOARD AND DIRECTOR PERFORMANCE ASSESSMENTS
The Board annually assesses its effectiveness in an effort to improve its performance.
Each year, the NCGC, in consultation with the Board Chair, determines the process by which assessments of the Board, individual Directors, and Committees will be conducted on their effectiveness and contribution. The process includes 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 Board members and is discussed at the NCGC. The Board considers the report, its findings and a set of priority actions for the year at a Directors-only session. Progress is then monitored throughout the year with oversight on that process by the NCGC.
The NCGC previously determined that while the traditional annual assessment process conducted by the Board Chair is robust and effective, from time to time the assessment process may be supplemented with the engagement of a third-party consultant to assist with the process of conducting the assessment in order to provide additional insights.
In determining the 2023 Board and Director performance assessment process, the NCGC, in consultation with the Board Chair, agreed the Board Chair would continue to follow the same process as was used for the 2022 Board and Director performance assessment and that the support of a third-party consultant was not required.
2022 Assessment
The 2022 assessment found that the Board and Director performance and effectiveness continued to be strong. Directors were of the view that the Board functions well from a governance perspective and exercises the right level of oversight. The prevalent themes that emerged related to strategy and organizational capacity. The 2022 assessment resulted in the identification of several areas of priority for 2023 related to the Companys strategy and management development. With the assistance of the NCGC, the Board Chair reviewed and reported to the Board on progress made in 2023 to address those priorities.
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2023 Assessment
The Chair of the Board interviewed each independent Director as part of the 2023 Board and Director performance assessment and solicited peer assessment and general feedback from each Director. A series of questions was sent to each Director for consideration in advance of each interview. The questions pertained to a number of themes, including:
| Emeras strategy and business, including risk management and ESG/Sustainability; |
| Organizational structure and capacity; |
| Board and Committee effectiveness; |
| Corporate governance; |
| Board composition and succession; |
| Individual Director effectiveness, including the Directors self-assessment of their own performance as a Director and an assessment of their peer Directors on the Board; and |
| The CEOs 2023 evaluation and the CEO goals and objectives for 2024. |
In 2023, upon completion of the assessment evaluation, the Chair completed a written report with proposed actions. This report, including the annual CEO assessment, was discussed in a separate, independent Director-only session.
The assessment of the Chair of the Board was conducted in a meeting of all Directors that excluded the Board Chair and the President and CEO and was led by the Chair of the NCGC. Directors were also given an opportunity to provide their assessment of the Chair of the Board in a one-on-one format with the Chair of the NCGC in advance of the meeting.
2023 Assessment Findings
The principal themes that came out of the 2023 Board and Director Performance Assessment related to strategy, organizational structure and capacity and Board effectiveness.
The Assessments findings addressed topics that included the Companys strategic goals, leadership development and succession planning, risk management processes, ESG and safety, all of which the Directors find are being appropriately managed and which will remain in focus for continued assessment and discussion in 2024.
Directors believe that the Board values and continues to maintain high standards of corporate governance.
The Assessment determined that Directors view the Company as having an effective Board with diverse skills and perspectives. The Board is also keenly focused on Emeras stakeholders, including our customers and shareholders.
2024 Objectives
While performing the Board and Director performance assessments, Directors proposed areas of future focus as it relates to strategy and organizational structure and capacity. These included:
| At each Board meeting, continue to discuss and engage with management on the Companys strategy and optimal balance sheet to achieve the Companys strategic objectives; |
| Continue to assess and advance how Emera approaches and participates in the energy transition and climate change for the benefit of our stakeholders; |
| Continue to explore and identify innovative technologies, including artificial intelligence, that could affect Emeras businesses over the longer term; |
| Strengthen executive talent across Emeras businesses by continuing to advance senior leadership development and succession planning; |
| Continue to enhance the Companys strong risk management processes, including in the area of cybersecurity; |
| Continue to advance improvement in safety performance across the business; |
| Assess and address various administrative suggestions with the goal of enhancing the effectiveness of the Board and its Committees; and |
| Continue to advance Board renewal in alignment with the Boards succession plan. |
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BOARD DIVERSITY
Emera believes that Board diversity is a strategic objective, leading to a broadening of perspectives in Board discussions, fostering more effective decision-making, and ultimately strengthening Board governance. Emera is focused on establishing and maintaining a Board with a diverse mix of experience, skills and backgrounds.
Emeras Board has adopted a Board Diversity Policy (Diversity Policy) which sets out a framework for promoting diversity on the Board. The Diversity Policy can be found at www.emera.com/governance.
In accordance with the Diversity Policy, when identifying candidates for nomination to the Board, the NCGC will consider:
| Emeras diversity objectives. For more about diversity, equity and inclusion at Emera, see the Diversity, Equity and Inclusion section in this Circular. |
| The diverse nature of the business environment in which Emera operates. |
| The need to maintain flexibility to effectively address succession planning and ensure that Emera continues to attract and retain highly qualified individuals to serve on the Board. |
| The benefits of diversity of Indigenous heritage, racial status, persons with disabilities and other diversity characteristics among Board members. |
| With respect to gender diversity, endeavour to ensure that women and men each comprise no less than 40 per cent of the independent Directors on the Board. |
As provided for under the Diversity Policy, the NCGC annually discusses and reviews the effectiveness of the Diversity Policy and agrees on the relevant measurable objectives for promoting diversity on the Board. The Board remains focused on continued promotion of diversity on the Board.
Diversity is incorporated into the Boards succession planning and recruitment processes in the following ways:
1. | When recruiting new Directors, the NCGC assesses the needs of the Board in the context of the mix of current Directors in terms of age, tenure, gender and other diversity characteristics as reflected in the Diversity Policy. |
2. | The NCGC considers the Board renewal principles, anticipated retirements of Directors and the Boards succession planning, balancing the need to maintain flexibility to ensure that Emera continues to attract and retain highly qualified individuals to serve on the Board. |
3. | When implementing its responsibilities under the Diversity Policy, the NCGC will take into account Emeras diversity objectives and the diverse nature of the business environment in which Emera operates. |
4. | On behalf of the Board, the NCGC retains independent recruiters to assist with Director recruitment by helping to identify qualified candidates of diverse backgrounds. In addition to women candidates, these recruiters are also mandated to seek diverse candidates reflecting diversity beyond gender, including Indigenous heritage, racial status, disabilities, LGBTQ2SI+ persons, and other diversity characteristics and who also reflect the skills and experience determined to be required by the NCGC following the assessments outlined in 1, 2 and 3 above. |
The NCGC has directed the Company to maintain an evergreen list of qualified potential Director candidates who self-identify as being a member of a diverse group, including Indigenous persons, racialized persons (persons who are non-Caucasian in race or non-white in colour), persons with a disability or persons who are LGBTQ2SI+.
The Board members voluntarily participate in an annual survey to provide self-identification data in support of the objectives in the Diversity Policy. Based on that survey:
| One Director nominee identifies as a racialized person (persons, other than Indigenous peoples, who are non-Caucasian in race or non-white in colour). |
| One Director nominee identifies as a member of the LGBTQ2SI+ community. |
| Four of the independent Director nominees are women and six of the independent nominees are men (seven of all Director nominees). Women therefore represent 40 per cent of the independent Director nominees (36 per cent of all Director nominees), which meets the requirement of 40 per cent women or men independent Directors under Emeras Diversity Policy. |
| None of the Director nominees identified as being Indigenous or persons with a disability. |
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Operating Company Board Diversity
Emera has made significant progress with respect to diversity on our operating company boards. Of the 20 external directors that serve on the boards of our four largest operating companies (Tampa Electric, Nova Scotia Power, Peoples Gas and New Mexico Gas), 45 per cent are female and 30 per cent have an ethnic, racial or visible minority status or are of Indigenous heritage. Diversity on our operating company boards remains an ongoing focus.
ORIENTATION OF DIRECTORS
New Directors receive an in-depth orientation to the Board and its Committees and to the Companys executive leaders, business, strategy, principal risks, financial information and governance practices. The orientation is designed to allow new Directors to effectively and efficiently step into their new role as Director and discharge their responsibilities. 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 Board 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 managements discussion & analysis 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 Companys management structure; |
(e) | Insider trading guidelines; |
(f) | Emeras Code of Conduct; and |
(g) | Minutes of previous Board meetings. |
CONTINUING EDUCATION FOR DIRECTORS
The Board, with the support and oversight of the NCGC, regularly seeks opportunities to update, educate and inform the Directors in areas they request or that management determines, are relevant to issues facing the Company.
The Board and Committees receive regular presentations from management updating Directors about market and industry conditions and trends that may impact the Companys business and influence its strategy. Additionally, the Board aims to receive specialized presentations on various matters of significance to the Company.
Annually, the Board has also been provided with opportunities for site visits to operational facilities to help Directors get to know leaders, understand management structure and more fully understand the business.
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Emera adopted a Guideline for Directors Attendance at Education Sessions, which is designed to encourage Directors to participate in education sessions from time to time that are directly related to the business of the Company and the performance of their duties as a Director of the Company. The Guideline provides that independent Directors who wish to attend an education session request the approval of the Board Chair to attend a particular education session and receive reimbursement of expenses in accordance with the Guideline. In 2023, Emera Directors participated in relevant education that included sessions presented by the Institute of Corporate Directors in Canada.
In 2023, Directors participated in education sessions, received education materials about specific topics and participated in site visits to operational facilities, as follows:
Topic |
Date | Participants | ||||
Business and operations | ||||||
1. | Climate Change Adaptation | February | RSC and Board Chair | |||
2. | Capital Markets Update | May | Board Members | |||
3. | Facilities site visits at Tampa Electric Company and Peoples Gas Systems, Inc. and related operations presentations | June | Board Members | |||
4. | Incident Response Management | June | Board Members | |||
5. | Cybersecurity Governance | September | Board Members | |||
6. | Canadas Modern Slavery Act | November | Board Members | |||
7. | Enterprise Risk | November | Board Members | |||
Market trends and regulatory updates | ||||||
8. | Current Developments in Securities Regulation and Financial Oversight | January | Audit Committee and Board Chair | |||
9. | Carbon Capture and Storage | June | Board Members | |||
10. | Legislative Initiatives in the United States to Support Clean Energy Transition | June | Board Members | |||
11. | Electrification | June | Board Members | |||
12. | Executive Compensation and Governance Trends | September | MRCC and Board Chair | |||
13. | Mandatory Sustainability Financial Disclosures | September | RSC and Board Chair | |||
14. | Mandatory Climate-Related Disclosure | November | Audit and Board Chair | |||
15. | Timing of the Energy Transition | December | Board Members |
2.3 Strategic Oversight
The Emera team shares a common purpose of energizing modern life and delivering a cleaner energy future for all. As the energy landscape continues to shift, our vision is to be the energy provider of choice for our customers, the employer of choice for our people, and a preferred choice for investors.
Driven by our Purpose and our Vision, Emeras strategy is focused on investing in the safe delivery of cleaner, affordable, reliable energy for our customers, which drives value and steady growth for our shareholders. Climate policy, customer demand and technology advancements are driving regulated rate base investment growth throughout our utility businesses, including cleaner energy resources, system hardening and reliability initiatives, digital and technology investments, in addition to the need to invest in system expansion to meet new customer growth and replace aging infrastructure.
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Led by the President and CEO, the management team works with the Board to set the strategy agenda each year. The Board and management meet regularly to discuss strategy; a dedicated and significant component of every scheduled Board meeting includes an update and discussion on strategy and related matters, including trends in the industry, growth initiatives, financial forecast updates and new risks and opportunities. These updates serve to keep the Board aware of changes in the market, industry and within Emera, as well as giving the Board an opportunity to provide insight and direction on strategy throughout the year.
Each year, at least one Board meeting is wholly dedicated to corporate strategy. In 2023, the Boards dedicated strategy session focused on the importance of balancing customer affordability, reliability and security of energy supply, and decarbonization through the energy transition. Discussion included potential investment opportunities arising from the energy transition and the impact of accelerative climate policies in the United States and in Canada. It also included an updated long-term scenarios and financial forecast, an overview of strategic signposts that management regularly monitors in its ongoing assessment and review, and updates on specific components of the Companys strategy.
SUSTAINABILITY
Emeras focus on sustainability is a key driver of our strategy and a demonstration of our values.
Governance and Risk Management
Strong governance and risk management are foundational to everything we do at Emera, including our approach to sustainability. In 2023, the Sustainability Management Committee (SMC) and the RSC remained focused on guiding our continued progress and overseeing our performance in this area.
The SMC, consisting of senior leaders from across the business and chaired by our President and CEO, provides executive oversight of our sustainability function and progress.
The role of the RSC is to assist the Board by overseeing Emeras risk management framework and allocation of responsibilities for risk management, and by also overseeing the Companys approach to sustainability and its performance relative to its sustainability objectives, including specifically climate-related risks, plans and disclosures.
Materiality Assessment
Emera is committed to transparency, accountability, understanding stakeholder expectations and improving disclosures on the material environment, social and governance priorities that matter most to stakeholders. We are currently updating our materiality assessment, with the support of a third-party expert, to identify and prioritize the issues that will inform our strategic sustainability planning and work as well as our future sustainability reporting.
Based on our previous materiality assessment, Emera has established a set of core environment, social and governance priorities that are regularly tracked by the SMC and have been formally integrated into Emeras Enterprise Risk Management Program, which is overseen by the RSC, and include:
ENVIRONMENT Air emissions CO2 emissions Methane emissions Climate adaptation Coal unit closures Low-carbon transition Waste management Water management Biodiversity
SOCIAL Community investment Customer affordability Diversity, equity and inclusion Indigenous relations Safety Talent management System reliability and grid resiliency
GOVERNANCE Business ethics and transparency Corporate governance Cybersecurity Sustainability governance Political and regulatory requirements
Mandatory Sustainability Disclosures
Emera has formed a cross-functional Task Force to help ensure our readiness for mandatory climate-related disclosures and other sustainability disclosures currently under consideration by certain sustainability standard setters and North American securities regulators. Our Task Force is actively monitoring and readying for these disclosure standards. In terms of standards, Emera has been aligned with the recommendations of the Task Force on Climate-related Financial Disclosures (TCFD) for many years in our sustainability reporting, including our climate reporting, helping prepare us for anticipated mandatory climate- related disclosures.
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The four core TCFD elements that ground our current climate disclosures include:
Climate Commitment and 2050 Net-Zero Vision
Building on its strong decarbonization track record, Emera is continuing its efforts with clear carbon reduction goals and a vision to achieve net-zero carbon emissions by 2050.
The Board of Directors is responsible for oversight of the Companys climate-related metrics and targets and monitors progress against those targets through the RSC. The RSC Chair reports to the Board of Directors on the RSCs deliberations at the next Board meeting.
The RSC is responsible for assessing the Companys approach to sustainability, including material climate risks and opportunities, and its performance relative to its sustainability objectives. Management reports to the RSC on the Companys progress in relation to climate-related metrics and targets at least annually.
In 2023, we achieved a 47 per cent reduction in CO2 over 2005 levels. With existing technologies and resources, we are working to achieve the following goals compared to corresponding 2005 levels (1):
| A 55 per cent reduction in carbon emissions by 2025 |
| An 80 per cent reduction in carbon emissions by 2040 |
| The retirement of our last existing coal unit no later than 2040 |
Emera seeks to achieve our goals and realize our net-zero by 2050 vision by adopting emerging technologies and working constructively with policymakers, regulators, partners, investors and our communities, while staying focused on enhancing reliability and seeking to minimize the cost impacts for customers. Emera tracks its progress towards achieving such goals using a Climate Commitment Tracking Tool it developed, which is managed and updated based on the work of its enterprise-wide Climate Commitment Tracking Committee, which meets regularly to assess such progress.
Diversity, Equity and Inclusion
We are committed to providing safe, diverse and inclusive workplaces where everyone is treated with dignity, fairness and respect. This starts with our leadership and extends across all levels of the Company. These beliefs are underscored in Emeras Values, Code of Conduct and our Respectful Workplace Policy.
Diverse and inclusive teams make us stronger they help us attract and retain the best people, support an engaged and productive team, and bring fresh perspectives and new ideas to the table. It also reflects Emeras communities and diverse customer base, enabling us to better understand the needs of our customers and the communities we serve.
(1) | Achieving our climate goals on these timelines is subject to external factors beyond our control, including government policies and regulatory decisions. |
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Emera and its operating companies are advancing a multi-year diversity, equity and inclusion (DEI) strategy:
| Aligning shared goals and best practices through Emeras company-wide DEI Council; |
| Supporting strong DEI employee networks and employee resource groups that build awareness and support across the business; |
| Adopting the Global Diversity, Equity and Inclusion Benchmarks (GDEIB) to measure our progress; |
| Gathering employee self-identification data to measure our diversity and to reflect our communities; |
| Including questions on our employee survey requesting feedback on diversity and inclusion; and |
| Connecting with communities to provide support through a $5 million fund to advance diversity and inclusion. |
At Emera we have DEI plans with proactive actions and activities that have been gathered into five pillars that align with the GDEIB. Each of the businesses across Emera have actions under each of the pillars that advances their current state of DEI and move it further along the maturity model.
Modern Slavery Act
Emera is committed to the human rights of employees, contractors and stakeholders across our supply chains. In Canada, the new Fighting Against Forced Labour and Child Labour in Supply Chains Act (commonly referred to as the Modern Slavery Act) requires Canadian government institutions and businesses that meet certain criteria, such as Emera, to annually report on their efforts to prevent and reduce the risk that forced labour or child labour is used by them or in their supply chain. The first report is required to be filed with the Canadian federal government by May 31, 2024. In preparation for these new requirements, the RSC has been given oversight of Emeras compliance with the Modern Slavery Act, including receiving and reviewing the annual report, which is ultimately approved by the Board. We have also developed and implemented a governance and compliance framework, including adopting the Reducing the Risk of Modern Slavery in Emeras Business and Supply Chains Policy, vendor supply chain due diligence, risk assessment tool and associated contractual provisions, employee and Director training, and annual compliance certifications within applicable Emera subsidiaries.
Gender Diversity and Women in Executive Roles
Emera monitors and encourages the development and progression of women into leadership positions at Emera and its operating companies. We believe that diversity among the senior executive teams at Emera is in the best interests of the Company and shareholders. The relative representation of women is considered when identifying potential candidates for executive officer appointments. It is also critical that each selection of executive officers be made and be perceived to be made on the merits of the individual and the needs of the Company at the relevant time. With these considerations in mind, Emera has not yet set specific targets for the representation of women in executive officer positions. However, as part of our DEI journey, targets for the representation of women in executive officer positions are being considered.
Eight of the 21 executive officers (1) at Emera Inc. and its major subsidiary (2) are women, representing 38 per cent of these positions. On Emera Inc.s broader senior executive leadership team, which includes Emera Inc.s executive officers, three of the 12 individuals are women, representing 25 per cent. In addition, 11 of the 23 senior-level positions at Emera Inc. beyond Emeras senior executive leadership team are held by women, representing 48 per cent, and three of our operating companies (Peoples Gas Systems, Inc., Emera Energy and Grand Bahama Power Company) are currently led by women executives. Across all Emera companies, 33 individuals, representing 39 per cent of persons in senior-level positions, are female.
(1) | The term executive officer is defined under applicable securities law. |
(2) | This term is defined under applicable securities law. Tampa Electric Company is Emeras major subsidiary under this definition. |
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|
REPRESENTATION OF WOMEN 25% of Emeras senior executive leadership team |
48% of senior-level positions at Emera Inc. |
39% of senior-level positions across the Emera Group of Companies |
40% independent Director nominees |
Management continues to be focused on helping ensure Emeras hiring and pay practices promote equity between men and women. Progress is being made and we remain committed to:
1. | Analyzing our demographics and data annually to: |
a. | Monitor the rates of women in leadership and senior leadership roles; |
b. | Undertake regular wage gap analysis to track progress and identify challenges by operating company; |
c. | Exercise selective pay increases if wage disparity exists; and |
d. | Examine our recruitment strategies to ensure equity in pay at entry into the organization. |
2. | Developing and promoting programs that are focused on increasing female participation in our industry, particularly for traditionally male-dominated roles. |
3. | Considering diversity in the development of talent pools to enhance our diversity for the future at all levels. |
Our Commitment to Safety
Safety is Emeras number one priority. Our goal is the elimination of serious injuries and fatalities (SIFs) across the Company. It is important that all people involved in our business are focused on safety and have the permission to only do something if they can do it safely. There is no acceptable injury associated with our work.
Our leaders are passionate about safety. In 2023, we more than doubled the number of leadership safety engagements by senior leaders with frontline team members. Part of our focus was also creating capacity to create psychologically safe workplaces. We strive to ensure all employees have the conditions to do their best work.
In 2023, we continued to improve our Total Recordable Incident Rate (OSHA) as well as the Lost Time Injury (LTI) Rate, which were both below our five-year rolling average. Indeed, in 2023 we achieved our lowest LTI rate ever on this important metric. For our employee base, we experienced one serious injury. We believe one serious injury is one too many, and it is important that all people return home safely to their families at the end of each workday.
From a public safety perspective, we experienced an increase in safety related incidents. These occurred in numerous cases where members of the public engaged in unsafe activities that put them in contact with our electrical assets. We take each of these situations very seriously and are actively reviewing our public safety systems and programming.
In 2023, Emera continued to roll out its energy-based hazard identification program, focused on SIF prevention, including concepts such as STKY (Stuff that Kills You) and hazardous energy control assessment (HECA). Increasing the capacity to identify and manage risk is a primary focus. Other program focus areas included contractor safety, safety leadership training, and behavioural aspects of safety management.
As a learning organization, we continually strive to discover best practices and learn from all incidents. To this end, we regularly bring our collective organizations and contractors together to discuss issues and share ideas. In 2023, we focused on improving our incident investigation process requiring all operating companies and contractors to continuously improve their practices to be the best they can be when it comes to safety.
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Investing in Our Communities
Through Emeras Community Investment Program, we are committed to supporting meaningful programs and initiatives in the communities where our employees live and work. Our commitment to being a good community partner starts with three key areas of focus: youth opportunities, innovation and entrepreneurship, planet and sustainability.
In 2023, Emera invested over $12 million in community initiatives in these areas and our employees volunteered over 37,900 non- working, self-reported volunteer hours to charitable organizations. In our Canadian businesses, employees reported more than 7,000 volunteer hours through the Good Neighbour Program. These reported hours were matched with Emera donations to these organizations.
Within our programs strategic focus areas, we consider opportunities through a DEI lens. Recognizing the important value this lens adds, the Emera group of companies launched the $5 million DEI Fund in 2021. Together with our operating companies in 2023, Emera invested over $1.6 million to specifically support organizations and initiatives advancing inclusion and diversity in our communities.
To capture our community investment value and impact, Emera works with the London Benchmarking Group (LBG) Canada. The LBG model provides the global standard for reporting community investment, presenting a consistent and credible framework for impact measurement. You can read more about our community investment program on our website (www.emera.com/community).
Information Security Oversight and Cybersecurity
Emera increasingly relies on information technology (IT) systems, as well as network and cloud 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.
Our reliance on technology exposes Emera to potential risks of business interruption or the unavailability, release, destruction or misuse of critical, sensitive or confidential information due to cyberattacks.
We seek to manage these risks by aligning to a common set of cybersecurity standards and policies derived, in part, from the National Institute of Standards and Technologys Cybersecurity Framework, by following program maturity objectives, through periodic security assessments, by exercising and improving cybersecurity incident readiness and response programs, and by employee communication and training. With respect to certain of its assets, the Company is required to comply with rules and standards relating to cybersecurity and IT including, but not limited to, those mandated by bodies such as the North American Electric Reliability Corporation, Northeast Power Coordinating Council, and Department of Homeland Security.
Directors receive cybersecurity training as part of our continuing education sessions (see Continuing Education for Directors earlier in this Circular).
The status of key elements of our cybersecurity program is reported to the RSC of the Board on a quarterly basis. In addition, the Board also oversees cybersecurity risk which is included in the risk dashboard/heat map provided to Directors at each regularly scheduled Board meeting. The Board also receives updates on cybersecurity and technological risks through the annual report it receives with respect to the Companys digital transformation strategy.
Information Technology
Emera relies on various IT systems to manage its operations. This subjects Emera to inherent costs and risks associated with maintaining, upgrading, replacing and changing these systems. Emeras digital transformation strategy, including investment in infrastructure modernization and customer-focused technologies, is driving increased investment in IT solutions, resulting in increased project risks associated with the implementation of these solutions. Emera manages these IT risks through IT asset lifecycle planning and management, governance, internal auditing and testing of systems, and executive oversight. Highlights of Emeras digital transformation strategy are reported to the Board annually.
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2.4 Risk Management
The Emera Board has a comprehensive and multi-faceted approach to its risk oversight. This includes responsibility for overseeing the implementation by management of appropriate systems to identify, report and manage the principal risks of Emeras business. It is responsible for overseeing the development of Emeras risk management framework and allocation of responsibilities for risk management, which it does with support from the RSC.
Emera and its operating companies apply common programs for risk identification and management. Each affiliate is governed by its own board, which allows for a focused approach to risk management oversight and governance.
The Board has endorsed a risk statement that articulates Emeras risk appetite. The risk statement sets out the Companys risk appetite across a number of areas and is intended to provide general guidance for decisions of the Company. The Board considers Emeras risk profile in its oversight of Emeras risk management by reviewing:
(a) | The annual identification and assessment of the principal risks of Emera; |
(b) | The process for ongoing monitoring, updating and reporting of the principal risks of Emera; |
(c) | The effectiveness of Emeras mitigation response to its principal risks; and |
(d) | The alignment of risk management with Emeras risk profile, its strategy and its organizational objectives, including capital and resources allocation. |
Further, a comprehensive and ongoing risk assessment is part of every major project the Company undertakes. The Board is also responsible for reviewing Emeras annual insurance program and its uninsured exposure.
Under the Boards oversight, management undertakes a robust cross-functional approach to the identification, evaluation and assessment of its high-impact enterprise risks. Risks are categorized as either primary, evolving or mature, and are tracked and reported on through a quarterly Risk Dashboard. Management considers the existing control environment, velocity of impact following the onset of a potential risk event as well as risk interdependencies, when assessing risks and developing appropriate mitigation plans and response protocols.
Additional in-depth analysis into certain principal risks is undertaken and reported to the Board (through the RSC, or directly). Board Committee oversight responsibilities for these principal risks are assigned per their respective Committee mandates (see Board Committees Risk Oversight below).
Board Committees Risk Oversight
Emera Board:
The Board has ultimate responsibility for risk oversight. Emeras risk management focus includes financial, strategic, and key operational risks including safety and environment.
The Board, in carrying out its responsibilities, delegates certain functions to the Committees of the Board. Each committee has responsibilities for specific aspects of risk oversight. |
g |
Emera Risk & Sustainability Committee (RSC) | Assist the Board with carrying out risk and sustainability oversight responsibilities, which encompasses oversight of Emeras Enterprise Risk Management framework, including the identification, assessment, monitoring, and management of enterprise risks. The RSC risk mandate includes oversight of climate and cybersecurity risk. | |||
Emera Management Resources & Compensation Committee (MRCC) |
Assist the Board with carrying out responsibilities for management resource issues and risks relating to compensation programs for executive officers. | |||||
Emera Health, Safety & Environment Committee (HSEC) |
Assist the Board with carrying out responsibilities relating to oversight of Emeras Health, Safety, and Environmental (HSE) matters, which includes oversight of enterprise risks relating to HSE. | |||||
Emera Audit Committee |
Assist the Board with oversight of responsibilities regarding Emeras financial risk exposures (financial derivatives, hedging activities, credit, and trading), integrity of financial statements, internal control systems, audit processes, compliance with legal and regulatory requirements and the administration of the Ethics Hotline process. | |||||
Operating Companies Board of Directors |
Emeras principal operating affiliates each have an established Board of Directors who are responsible for oversight of affiliate enterprise risks. Affiliate Boards are chaired by an Emera Executive Officer and have external directors. |
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2.5 Ethical Business Conduct
The Board is committed to sustaining a culture of integrity and ethical business practices throughout the Company.
CODE OF CONDUCT
The Board promotes a culture of ethical business conduct and has adopted our Code of Conduct (Code), which establishes a standard of ethical business conduct that is expected from all of our Directors, officers and employees. We have implemented annual Code training for all employees to support compliance and requires Directors, officers and employees of Emera and its subsidiaries to acknowledge they have read, understand, are currently in compliance with and agree to comply with, our Code when they join the Company, and annually thereafter. In addition, Emera and its subsidiaries expect each of their contractors, suppliers, business partners, consultants and agents to act in a manner consistent with the Code.
The Code is available on Emeras website at www.emera.com/about-us/who-we-are/code-of-conduct, 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 and makes revisions to update the content with regard to best practices. Individuals are encouraged under the Code to, in good faith, seek advice, raise concerns, and report suspected misconduct related to Emeras business. Emera will not tolerate retaliation, threats of retaliation, termination from an Emera Company, or discrimination that is directly or indirectly related to the good faith disclosure of suspected unethical activities or violations of laws, regulations or policies.
The Board monitors compliance with the Code, including as detailed in Related Party Transactions. In addition, the Board has oversight of the Companys Ethics Hotline in the manner described below.
RESPECTFUL WORKPLACE
The Code is supported by other key policies, including Emeras Respectful Workplace Policy. The Respectful Workplace Policy applies to all Directors, officers and employees of Emera and its subsidiaries and is focused on providing a respectful and inclusive environment that is free from discrimination, harassment, sexual harassment, and bullying in the workplace and such conduct outside the workplace that contributes to a hostile work environment.
Comprehensive mandatory training is required when an employee joins the Company, which includes modules on harassment, sexual harassment, discrimination and bullying, and outlines available resources for employee support or to raise concerns. In addition, the Respectful Workplace Policy is included as part of annual Code training.
ETHICS HOTLINE
The Company has established a confidential and anonymous Ethics Hotline hosted by an independent external service provider. The Ethics Hotline is available to employees, contractors and third parties to report allegations of non-compliance with the Code. The internal audit department (Audit Services) is responsible for administering the Ethics Hotline process and ensuring all reports are investigated by the Company. Committees of the Board receive periodic updates on Ethics Hotline reports that fall within the scope of the Committees mandate based on the nature of the matter. For example, the Audit Committee receives updates related to financial reporting, accounting, auditing and business integrity matters; the MRCC receives updates related to people, wellness and workplace culture matters; and the HSEC receives updates related to safety and environment matters.
CONFLICTS OF INTEREST
Directors are required to declare any conflict of interest that they may have in a matter before the Board. In any matter requiring approval of the Board, a Director is prohibited by the Articles from voting in respect of the matter in which the Director is interested.
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RELATED PARTY TRANSACTIONS
Transactions between Emera and related parties are monitored in several ways to determine that such transactions comply with applicable laws, regulatory rules and the Code. In particular:
| The Audit Committee oversees the disclosure in Emeras financial statements of related party transactions that are required to be disclosed pursuant to United States Generally Accepted Accounting Principles. In the ordinary course of business, Emera provides energy and other services and enters into transactions with its subsidiaries, associates and other related companies on terms similar to those offered to non-related parties. All material amounts are under normal interest and credit terms. Additional disclosure is provided in Emeras financial statements regarding more significant transactions between Emera and its associated companies. |
| Under the Articles, any Director who has an interest in a transaction with the Company must disclose the existence and nature of the interest to the Board of Directors and such Director may not participate or vote on the matter. |
| Under the Code, Directors, officers and employees of Emera cannot own more than a 10 per cent interest in, or act in the capacity of a director, officer, partner, consultant, employee or agent for a supplier, contractor, subcontractor, Emera customer, competitor or any other person or organization with which Emera has a similar relationship, without the express prior approval of their manager, or in the case of a member of the Board of Directors, the Board Chair. They must also seek similar approval when a company, partnership or business in which they, or a member of their family, own more than a 10 per cent interest, or in which they are a director, partner, officer, consultant, employee or agent is seeking to do business with Emera. |
| Also, as described in the Code, Emeras operating companies are regulated by several Canadian, American and Caribbean energy regulators. Certain of these regulators have imposed specific codes and standards of conduct that address matters such as undue discrimination and preferential treatment between regulated companies and their affiliates. These rules may apply to and restrict arrangements between operating companies to conduct business or share employees. Emeras operating companies have created separate codes and standards of conduct addressing these matters. Directors, officers and employees are required by the Code to be aware of, and comply with, these operating company rules at all times. |
| The NCGC oversees the management of any conflicts of interest or potential conflicts of interest involving Directors. |
The Audit Committee is responsible for annually receiving and reviewing a report on executive officers compliance with the Code and receives quarterly reports on the Companys ethics program, including information on reports received through the Ethics Hotline (see Ethics Hotline, above) or submitted directly to Audit Services.
2.6 Transparency and Disclosure
DISCLOSURE POLICY AND PRACTICES
The Board has adopted a Disclosure Policy to ensure all communications of material information to the investing public about the Company are accurate, that they fairly present in all material respects the Companys financial condition and its results of operations and are made on a timely basis. For the full text of the Disclosure Policy, visit www.emera.com/governance.
Emera has established an executive Disclosure Committee responsible for overseeing the Companys disclosure practices. The Companys President and CEO, the CFO, the leaders of its businesses, and senior management responsible for legal, finance, investor relations, and communications functions are members of the Disclosure Committee, which meets at least quarterly. Members of the Disclosure Committee are responsible for reviewing all core disclosure documents containing material information, including the Companys managements discussion and analysis and financial statements prior to their being presented to the Audit Committee and Board for approval.
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ENGAGEMENT
Emera has a mature and robust program of engaging with financial analysts, investors and other stakeholders through direct meetings, investor events, quarterly analyst calls and other initiatives. In 2023, Emeras executives met with many of the Companys shareholders, including nearly all of Emeras active top 20 investors. An investor day is targeted to be held every 12 to 18 months, with the last investor day being held on March 2, 2023. Shareholders can also participate in our annual meeting via live webcast. Directors receive detailed reports on the shareholder engagement activity by management at each regularly scheduled meeting of the Board.
The Directors are interested in shareholders views about the Company, its governance and its operations. The Board oversees systems for receiving feedback from shareholders and it monitors feedback received by the Company.
Shareholders are encouraged to provide feedback to management and/or the Board |
Contact information | |
To reach management: President and CEO Chief Financial Officer Executive Vice President and General Counsel Corporate Secretary To reach the Board: (1) Chair of the Board Chair of a Committee |
Email: Scott.Balfour@emera.com Email: Greg.Blunden@emera.com Email: Mike.Barrett@emera.com Email: Brian.Curry@emera.com
Email: info@emera.com Email: info@emera.com |
(1) | Confidential communications with the Chair of the Board or another Board member should be mailed to the address below marked Private and Confidential. |
The Board Chair and other Directors engage with shareholders directly. In 2023, the Board Chair along with members of Management met with one of our largest shareholders. The meetings discussion topics included Emeras Board composition and Board oversight of risk.
The Board recognizes that shareholder engagement is an evolving practice and plans to review its practices annually with a view to enhancing their effectiveness.
Shareholder engagement process |
Contact information | |
Shareholders may communicate with the Chair of the Board or other independent Directors by sending them a letter using regular mail or other means of delivery. If the envelope is marked Private and Confidential, it will be delivered, unopened, to the Chair of the Board of Directors, or such other independent Director to whom it is addressed. | Attention: Chair of the Board of Directors of Emera Inc. (or Name of Independent Director)
P.O. Box 910, Halifax, Nova Scotia B3J 2W5
in a sealed envelope marked Private and Confidential |
Shareholder Proposals
Shareholders can submit proposals to be considered at an annual meeting of the Company provided they are duly submitted in advance and included in the Management Information Circular for the meeting. A shareholder intending to submit a proposal for consideration at an annual meeting must comply with the applicable provisions of the Nova Scotia Companies Act and the Articles. This includes compliance with the requirements for Director nominations contained in the Articles where the proposal includes a nomination for the election of an individual to the Board of Directors. In accordance with and subject to the requirements of the Companies Act, the Company will include a shareholder proposal in its Management Information Circular prepared for an annual meeting provided such proposal was received by the Company at least 90 days before the anniversary date of the previous annual meeting and provided such proposal is required by the Companies Act to be included in such Management Information Circular. Regardless of whether you are submitting a proposal, the nomination of Directors is still subject to compliance with the Articles, which require notice of the nomination not less than 30 days prior to the date of the annual meeting. Should you have any questions about shareholder proposals or Director nominations, please contact Emeras Corporate Secretary using the contact information in the Notice of Meeting at the beginning of this Circular.
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2.7 Committees of the Board of Directors
AUDIT COMMITTEE
Kent Harvey (Chair)
Paula Gold-Williams
Lynn Loewen
Ian Robertson
Andrea Rosen
| Committee Members are 100% independent |
| Mr. Harvey is the former CFO for PG&E Corporation |
| Ms. Gold-Williams is a Certified Public Accountant and former CFO for CPS Energy |
| Ms. Loewen was a former CFO with Air Jazz |
ROLE OF THE AUDIT COMMITTEE
The Audit Committee assists the Board in discharging its oversight responsibilities concerning the integrity of Emeras 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 is responsible for reviewing and recommending to the Board the annual financial statements and all related managements discussion and analysis and earnings press releases. The Audit Committee has also been delegated the authority by the Board to review and approve the interim financial statements and related managements discussion and analysis and earnings press releases.
The Audit 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 Audit Committee, and the Audit Committee oversees the work of the external auditors concerning the preparation or issuance of the auditors reports or the performance of other audit, review or attest services for Emera.
The Companys lead internal auditor also reports directly to the Audit Committee, and the Audit Committee approves the appointment, remuneration, removal and replacement of the lead internal auditor.
The Audit Committee reviews and approves the internal audit plan, including activities, organizational structure, staffing, qualifications and budget and all major changes to the plan.
The Audit Committee reviews and discusses Emeras major financial risk exposures and the process management has taken to monitor and control such exposures, including the use of financial derivatives, hedging activities, credit and trading risks.
The Audit Committee reviews management controls and processes concerning the administration of investment activities, financial reporting, and financial performance and funding of the pension plans.
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ACTIVITIES OF THE AUDIT COMMITTEE IN 2023
Committee Charter, the Audit Committee performed the following key functions in 2023:
1. | Reviewed regular updates on accounting and disclosure issues; |
2. | Reviewed developments in securities regulation and financial oversight; |
3. | Reviewed an annual credit and market price risk report; |
4. | Reviewed an annual tax report, which provides an update on material changes to tax policies, legislation, tax planning, tax payments and reporting and pending tax audits or assessments; |
5. | Reviewed and approved the hiring of a new lead internal auditor, and their remuneration; |
6. | Reviewed the 2022 performance of the lead internal auditor; |
7. | Reviewed an annual compliance report and quarterly compliance reports of the Chief Compliance Officer; |
8. | Reviewed quarterly reports of material litigation; |
9. | Reviewed quarterly reports on legal and regulatory compliance; |
10. | Reviewed and recommended to the Board of Directors for approval the audited 2022 year-end financial statements, managements discussion and analysis, and press release; |
11. | Reviewed and approved interim financial statements, managements discussion and analysis, and press releases; |
12. | Reviewed the CFOs quarterly reports on the Companys financial results and forecasts; |
13. | Provision of oversight of the work of managements Disclosure Committee; |
14. | Reviewed regular reports by management about the Companys compliance program under National Instrument 52-109 and the Sarbanes-Oxley Act; |
15. | Reviewed quarterly reports of internal Audit Services and quarterly reports on the Companys Ethics program, including fraud investigations, provided by the lead internal auditor; |
16. | Reviewed and approved updates to the Companys internal Audit Services Charter; |
17. | Reviewed and approved the assurance and advisory plan, including resource structure and budget for the internal Audit Services function; |
18. | Reviewed pension plan performance in 2022; |
19. | Reviewed the 2023 Audit Plan of the external auditors, EY; |
20. | Reviewed voting results from the 2023 Annual Shareholder Meeting for the appointment of EY as external auditor; |
21. | Evaluated the external auditors, including the lead external audit partners qualifications, performance, professional skepticism, and independence; |
22. | Reviewed the status of climate-related disclosure standards and work to prepare for the new requirements; |
23. | Reviewed and approved the 2024 audit and non-audit services fees of EY; |
24. | Reviewed the Audit Committee Charter, and recommended amendments to the Charter that were reviewed by the Nominating and Corporate Governance Committee and then approved by the Board of Directors; and |
25. | Provided feedback on the performance of the CFO for the prior year. |
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HEALTH, SAFETY AND ENVIRONMENT COMMITTEE (HSEC)
James Bertram (Chair)
Paula Gold-Williams
Kent Harvey
Lynn Loewen
Committee Members are 100% independent
ROLE OF THE HSEC
The purpose of the HSEC is to assist the Board in carrying out its responsibilities relating to oversight and coordination of Emeras health, safety and environmental programs, and making recommendations to the Board as appropriate.
The HSECs role is to review the Companys performance on health, safety and environmental matters, including compliance with legislation, and conformance with applicable management system standards, industry standards and best practices. It reviews emergency response plans and programs.
The HSEC oversees the Companys health, safety and environmental systems and policies. It reviews actions taken by the Company to identify and manage risks. This oversight extends to Emeras subsidiaries.
Any significant safety or environmental incidents relating to the Companys assets or operations will be reviewed by the HSEC, including those involving personnel safety, contractor safety, public safety or environmental damage. The HSEC oversees managements response to any significant regulatory findings, orders, reports and/or recommendations related to health, safety and the environment.
ACTIVITIES OF THE HSEC IN 2023
The HSEC met three times in 2023 and, in line with its mandate, undertook the following key activities:
1. | Reviewed the HSEC Charter and Work Plan and recommended amendments to the HSEC Charter with respect to the HSECs responsibility for reviewing enterprise risks within its mandate which were then approved by the Board of Directors; |
2. | Reviewed the safety and environment objectives and measures for the Companys 2023 incentive compensation Scorecard; |
3. | Received and reviewed updates on health and wellbeing initiatives within the Company and its affiliates; |
4. | Reviewed Emeras Occupational Safety & Health Policy Statement; |
5. | Received and reviewed reports on the environmental and safety performance of Emeras businesses; |
6. | Oversaw Emeras corporate safety and environmental auditing program; |
7. | Reviewed an update on the software supporting incident management, risk management, audits and inspections and associated workflows; |
8. | Received and reviewed regular reports on safety and environmental incidents, including root cause analysis and corrective action plans; |
9. | Reviewed the Companys safety and environmental priorities; |
10. | Oversaw changes in the organizational structure of Emeras safety and environment team to create efficiencies and enhance accountability; |
11. | Reviewed a report on enterprise risks within the oversight responsibility of the HSEC; |
12. | Reviewed an overview of Emeras Gas Operations Management System; |
13. | Reviewed a report on industry approaches to public safety risk; |
14. | Reviewed the emergency response plans and programs for Emera and its businesses; and |
15. | Received reports on Emeras Ethics program. |
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MANAGEMENT RESOURCES AND COMPENSATION COMMITTEE (MRCC)
Henry Demone (Chair)
James Bertram
Karen Sheriff
Jochen Tilk
Committee Members are 100% independent
ROLE OF THE MRCC
The MRCC 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 CEOs compensation and supports the Chair of the Board in recommending such goals and objectives for the current year to the Board of Directors. The MRCC ensures that an assessment of the President and CEOs performance in relation to these goals and objectives is completed. It makes recommendations to the Board of Directors relating to the President and CEOs total compensation, including participation in incentive compensation and equity-based plans. It also makes recommendations about senior managements total compensation and incentive compensation plans and equity-based plans. It approves grants of stock options, performance share units (PSUs), restricted share units (RSUs) and deferred share units (DSUs) in accordance with the provisions of the respective plans. It reviews executive compensation disclosure prior to the Company releasing such information to the public.
The MRCC recommends executive officer appointments to the Board of Directors for approval. It supports and contributes to the Boards 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 Emeras 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 regularly reviews managements direction and decisions made in support of labour and employee relations. It also reviews the design of pension plans for the Companys 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 MRCC 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 that are not aligned with Emeras business strategy. |
ACTIVITIES OF THE MRCC IN 2023
The MRCC met five times in 2023 and in accordance with its mandate, performed the following key functions:
1. | Reviewed the 2022 Scorecard results for Emera and its operating companies and recommended approval by the Board of Directors; |
2. | Reviewed executive performance in 2022 and recommended 2023 executive compensation to the Board of Directors; |
3. | Reviewed and recommended Emeras 2023 Corporate Scorecard to the Board of Directors; |
4. | Reviewed operating company Scorecards for 2023; |
5. | Reviewed and approved long-term incentive plan payouts in respect of 2022 and grants for 2023; |
6. | Reviewed plans for executive succession and leadership development; |
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7. | Reviewed annual succession plans for senior management and provided oversight of succession planning process for President and CEO; |
8. | Reviewed and recommended to the Board of Directors the 2023 compensation of the CEO; |
9. | Received and reviewed updates on trends in executive compensation and an analysis of gender equity within Emera; |
10. | Reviewed employee engagement survey results; |
11. | Reviewed an annual compensation design risk assessment; |
12. | Oversaw compensation-related disclosure in Emeras 2023 Management Information Circular; |
13. | Reviewed a DEI dashboard setting forth data and analysis on the DEI strategies established by Emera; |
14. | Received updates in respect of Emeras Ethics program and Respectful Workplace program; |
15. | Received and reviewed reports under Emeras Ethics program; |
16. | Reviewed the MRCC Charter; |
17. | Issued a request for proposals for compensation advisor services to test the market for such services, and re-engaged the incumbent; and |
18. | Reviewed and approved the 2023 Work Plan of the compensation consultants. |
NOMINATING AND CORPORATE GOVERNANCE COMMITTEE (NCGC)
Andrea Rosen (Chair)
Henry Demone
Karen Sheriff
Jochen Tilk
Committee Members are 100% independent
ROLE OF THE NCGC
The NCGC assists the Board with a variety of matters relating to corporate governance. One of its primary duties is to provide the Company with a list of nominees for election as Directors to be included in the Companys Management Information Circular prior to each Annual Meeting of Shareholders of the Company. The NCGC is responsible for identifying, considering and recruiting people qualified to become Directors, having regard to the skills, experience and qualifications of possible candidates, the key selection criteria approved by the Board, and taking into account the considerations outlined in Emeras Board Diversity Policy.
The NCGC oversees the succession of Directors in accordance with the Boards Renewal Principles and following a full skills assessment, having regard to the anticipated retirement of Directors and, where applicable, the Chair of the Board and Committee Chairs.
The NCGC is responsible for developing and communicating the Companys approach to corporate governance issues, and reviews and approves Emeras disclosure of its corporate governance practices. The Committee keeps abreast of evolving governance best practices and regularly evaluates the governance practices of Emera. It reviews any disclosure of the Companys corporate governance practice in accordance with applicable rules and regulations.
The NCGC is responsible for 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. It also makes recommendations to the Board on all components of non-employee Director compensation, including the Board Chair and Committee Chairs. Another area of responsibility includes 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.
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ACTIVITIES OF THE NCGC IN 2023
The NCGC met six times in 2023 and, in accordance with its mandate, undertook the following activities:
1. | Reviewed the plan for Director succession and undertook recruitment activity to identify potential candidates for the Board of Directors; |
2. | Together with the Board Chair, established a plan and process for Board Chair succession; |
3. | Reviewed the Board Renewal Principles and the application of those Principles considering the average age and tenure of each member of the Board of Directors; |
4. | Reviewed the Board Tenure Guideline; |
5. | Recommended to the Board of Directors for approval, Director nominees for election at Emeras 2023 Annual Meeting of Shareholders; |
6. | Recommended to the Board of Directors the re-election of the Chair of the Board; |
7. | Recommended to the Board of Directors the selection of Audit Committee financial experts for the purpose of Emeras Form 40-F filed with the United States Securities and Exchange Commission; |
8. | Reviewed and recommended to the Board of Directors for approval disclosure in respect of Director nominees, Director compensation and the corporate governance practices for Emeras 2023 Management Information Circular; |
9. | Oversaw the conduct of a survey of Emera Directors to seek voluntarily self-identification for diversity attributes; |
10. | Reviewed the Board of Directors Charter; |
11. | Reviewed the Board Diversity Policy; |
12. | Monitored the Companys corporate governance practices against relevant best practices at leading corporations; |
13. | Reviewed and recommended to the Board of Directors an amendment the Companys corporate governance practices regarding the process for Directors accepting a position on the board of another company; |
14. | Reviewed the program of Directors and Officers insurance coverage; |
15. | Reviewed and recommended to the Board of Directors amendments to Emeras Code of Conduct; |
16. | Reviewed compliance with Emeras Director Share Ownership Guideline; |
17. | In consultation with the Chair of the Board, determined the process for conducting the annual Board and Director performance assessment; |
18. | Reviewed and recommended to the Board of Directors revisions to the Audit Committee Charter; and |
19. | Reviewed and recommended to the Board of Directors revisions to the NCGC Charter. |
RISK AND SUSTAINABILITY COMMITTEE (RSC)
Jochen Tilk (Chair)
Lynn Loewen
Ian Robertson
Karen Sheriff
Committee Members are 100% independent
ROLE OF THE RSC
The role of the RSC is to assist the Board with the matters relating to risk and sustainability and making recommendations to the Board as appropriate.
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The RSC oversees Emeras risk management framework and allocation of responsibilities for risk management. It does this by receiving and reviewing with management:
(a) | The Companys Enterprise Risk Management function, governance and program framework that management employs to identify, assess, monitor and manage enterprise risk; |
(b) | The quarterly Risk Dashboard and Heat Map to assess whether the appropriate key enterprise risks have been identified and are being addressed; |
(c) | The Companys assessments of identified High-Impact Risks and its prevention and mitigation strategies and plans to address them; |
(d) | The Companys Risk Statement; |
(e) | The annual report of the Companys insurance risk transfer program; |
(f) | The quarterly reports on the Companys cybersecurity program; and |
(g) | Periodic reports on the Companys business continuity programs. |
The RSC also oversees the Companys approach to sustainability and its performance relative to its sustainability objectives. To do this, it:
(a) | Reviews the sustainability governance and program framework and policies that management employs to monitor, manage and report on sustainability risks; |
(b) | Receives and reviews periodic reports of managements Sustainability Management Committee on the status of material sustainability risks identified by that Committee; |
(c) | Receives and reviews the Companys annual Sustainability Report; |
(d) | Receives, reviews and, where appropriate, recommends to the Board, the Companys annual report under the Modern Slavery Act; |
(e) | Reviews and, where appropriate, recommends to the Board, managements proposed public sustainability commitments; and |
(f) | Monitors and reports to the Board on emerging sustainability risks and trends. |
ACTIVITIES OF THE RSC IN 2023
The RSC held three meetings in 2023 and, in accordance with its mandate, performed the following key functions:
1. | Reviewed and recommended revisions to the Committees Charter as set forth in the RSC Charter, including incorporating oversight of compliance with the Modern Slavery Act into the mandate of the RSC; |
2. | Received and reviewed regular cybersecurity updates; |
3. | Reviewed Emeras Risk Management Governance Framework; |
4. | Received and reviewed the quarterly Risk Dashboard and Heat Map, which captures the major enterprise risks, including primary, mature and evolving risks, as determined by management. As part of the review, the RSC considered feedback from a survey administered to individual Board members regarding Emeras enterprise risks; |
5. | Reviewed and approved changes to Emeras Risk Statement; |
6. | Received and reviewed analysis of carbon policy risk environment; |
7. | Received and reviewed analysis of potential impacts of shifts in public policy or regulatory constructs on Emeras business objectives; |
8. | Received and reviewed an annual insurance report; |
9. | Reviewed Emeras sustainability governance and program framework; |
10. | Reviewed ESG reports that capture Emeras progress on material ESG priorities and identified ESG trends; |
11. | Reviewed the compliance program and governance framework to address Emeras obligations under the Modern Slavery Act; |
12. | Reviewed an overview of and provided comments on the draft 2022 Emera Sustainability Report; |
13. | Received an annual update on the Companys progress on its climate commitment metrics and targets; |
14. | Oversaw the conduct of Director education sessions on climate change science, climate change governance and ESG disclosure requirements; |
15. | Received presentations on our climate adaptation framework and planning; and |
16. | Received updates and a presentation on sustainability disclosure standards and work being undertaken to ensure alignment of Emeras climate disclosures and the potential new requirements. |
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2.8 | Director Compensation |
The Board of Directors determines the compensation for the Companys 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; |
| Attract and retain highly skilled and experienced individuals to serve on Emeras Board; |
| Ensure alignment with shareholders long-term interests; and |
| Support Directors independence from management. |
2023 COMPENSATION RATES FOR DIRECTORS
Listed below are the annual compensation rates for non-executive Directors in 2023.
In 2023, the annual retainer for each Director was $252,500, of which $160,000 was payable in DSUs and $92,500 in cash. Subject to Emeras share ownership guideline (as described later in this Circular), Directors can elect to receive some or all of their cash compensation in the form of additional DSUs. 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.
The Chairs annual retainer is an all-inclusive fee, meaning the Board Chair receives no meeting fees or any other retainer for serving as Emeras Board Chair. The all-inclusive annual retainer of the Board Chair in 2023 was $450,000. This was comprised of $225,000 in DSUs and $225,000 in cash.
For information about changes to Director Compensation in 2024, see the section below entitled Annual Review and Changes for 2024.
Annual retainers for Directors in 2023 |
Cash amount ($) | DSUs ($) | Total ($) | |||||||||
Chairs retainer |
225,000 | 225,000 | 450,000 | |||||||||
Directors retainer |
92,500 | 160,000 | 252,500 | |||||||||
Audit Committee Chairs retainer |
27,500 | N/A | 27,500 | |||||||||
Audit Committee members retainer |
12,500 | N/A | 12,500 | |||||||||
Management Resources and Compensation Committee Chairs retainer |
22,500 | N/A | 22,500 | |||||||||
Management Resources and Compensation Committee members retainer |
10,500 | N/A | 10,500 | |||||||||
Nominating and Corporate Governance Committee Chairs retainer |
22,500 | N/A | 22,500 | |||||||||
Nominating and Corporate Governance Committee members retainer |
10,500 | N/A | 10,500 | |||||||||
Health, Safety and Environment Committee Chairs retainer |
22,500 | N/A | 22,500 | |||||||||
Health, Safety and Environment Committee members retainer |
10,500 | N/A | 10,500 | |||||||||
Risk and Sustainability Committee Chairs retainer |
22,500 | N/A | 22,500 | |||||||||
Risk and Sustainability Committee members retainer |
10,500 | N/A | 10,500 |
Each Director is entitled to an annual travel allowance of $10,000.
Members of ad hoc committees of the Board receive meeting fees ($1,750 in-person meeting fee; $1,250 videoconference/ telephone meeting fee) for their participation in each committee meeting, but typically receive no annual retainer for being a member of an ad hoc committee because of the nature of the committees existence, having generally been established for a specific purpose and a temporary period of time. For further information on the Companys committees, see Committees of the Board of Directors earlier in this Circular.
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TOTAL DIRECTOR COMPENSATION IN 2023
Compensation is made up of applicable retainers and the annual travel allowance of $10,000.
The table below details the total compensation paid to Directors in 2023. The columns under the headings DSUs awarded and DSUs held show detailed information about DSUs received by Directors as compensation.
Mr. Balfour is not included in the table as his compensation for service as Emeras President and CEO is disclosed in the Statement of Executive Compensation later in this Circular. He does not receive any additional compensation for his services as a member of the Board of Emera or as a member of the Board of any of Emeras subsidiaries or investments.
Total Director Compensation in 2023
DSUs awarded | DSUs held | |||||||||||||||||||||||||||
Director |
Fees earned in 2023 ($) (1) |
All other compensation ($) |
Total ($) | 2023 Share-based awards ($) (2) |
Value of DSUs vested during 2023 ($) (3) |
Change in value of DSUs held in 2023 ($) (4) |
Market value of total DSU holdings ($) (5) |
|||||||||||||||||||||
James Bertram |
295,500 | N/A | 295,500 | 295,500 | 359,528 | (35,272 | ) | 1,583,099 | ||||||||||||||||||||
Henry Demone |
295,500 | N/A | 295,500 | 160,000 | 262,127 | (55,003 | ) | 2,170,171 | ||||||||||||||||||||
Paula Gold-Williams (6) |
330,090 | N/A | 330,090 | 330,090 | 339,721 | (6,452 | ) | 563,549 | ||||||||||||||||||||
Kent Harvey (6) (7) |
350,420 | 8,213 | 358,633 | 160,000 | 218,248 | (31,649 | ) | 1,316,130 | ||||||||||||||||||||
Lynn Loewen |
296,000 | N/A | 296,000 | 296,000 | 440,665 | (78,193 | ) | 3,153,147 | ||||||||||||||||||||
Ian Robertson |
285,500 | N/A | 285,500 | 285,500 | 293,992 | (5,673 | ) | 490,772 | ||||||||||||||||||||
Andrea Rosen |
297,500 | N/A | 297,500 | 297,500 | 549,079 | (135,104 | ) | 5,235,796 | ||||||||||||||||||||
Richard Sergel (6) (7) |
130,599 | 5,377 | 135,976 | 63,123 | 101,781 | (46,811 | ) | | ||||||||||||||||||||
Jackie Sheppard |
460,000 | N/A | 460,000 | 460,000 | 769,589 | (166,636 | ) | 6,550,132 | ||||||||||||||||||||
Karen Sheriff |
286,779 | N/A | 286,779 | 286,779 | 309,407 | (13,212 | ) | 767,729 | ||||||||||||||||||||
Jochen Tilk |
306,000 | N/A | 306,000 | 306,000 | 364,134 | (32,177 | ) | 1,480,356 |
(1) | The Fees earned in 2023 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 2023 that was allocated to DSUs. DSUs granted in 2023 are based on the value of the Emera common share closing price on December 30, 2022 of $51.75. |
(3) | This column shows the value of all DSUs received in 2023, including received as dividend equivalents during the year, multiplied by the December 29, 2023 Emera common share closing price of $50.30. |
(4) | This column shows the change in value of all DSUs held by each Director at the beginning of the year because of the change to the Emera common share closing price from $51.75 at the beginning of the year to $50.30 on December 29, 2023. |
(5) | This column shows the value of all DSUs held by each Director at the end of 2023 based on the December 29, 2023 Emera common share closing price of $50.30. |
(6) | As US-domiciled Directors, the annual cash retainer, committee retainers, and travel allowance were paid to Ms. Gold-Williams, Mr. Harvey, and Mr. Sergel in US dollars, using a one-to-one conversion rate to the Canadian dollar. |
(7) | Mr. Sergel and Mr. Harvey also each 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 Emeras Directors who served on the Boards of its subsidiaries.
COMPENSATION OF EMERA DIRECTORS ON OPERATING COMPANY BOARDS
The Emera Board of Directors, on the recommendation of the NCGC, also determines the compensation to be received by Emera Directors who serve on the Boards of Emeras 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 table above entitled Total Director Compensation in 2023.
Emera US Holdings Inc. is a United States holding company that holds certain United States-based investments of Emera. Members of the Board of Directors of Emera US Holdings Inc. receive an annual retainer of $10,000 USD for serving on its Board, plus $1,000 USD for any meetings.
Mr. Sergel was a Director of Emera US Holdings Inc. until his resignation on May 24, 2023 (concurrent with him ceasing to be a Director of Emera at our 2023 Annual Meeting) and received $5,377 in compensation in 2023 for serving on its board. Mr. Harvey became a Director of Emera US Holdings Inc. effective May 24, 2023 and received $8,213 in compensation in 2023 for serving on its board. (1)
(1) | Compensation amounts are stated in Canadian dollars. |
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ANNUAL REVIEW AND CHANGES FOR 2024
The NCGC annually reviews the compensation of Directors to help ensure it is appropriate.
The NCGC reviews the compensation practices of publicly traded companies similar in size and complexity to Emera to determine whether the Directors are appropriately compensated for the responsibilities and risks involved in being a member of the Companys Board. The review is based upon publicly available information concerning Directors compensation and the advice of Mercer (Canada) Limited, a third-party compensation consultant.
The NCGC has adopted the 50th percentile as a target for Director compensation and has determined it would be appropriate for Emera to continue to position total compensation of Directors at approximately the median of its peer group, which is the average of the Canadian and United States sub-groups. The peer group used for Director compensation purposes is the same as the benchmarking comparator group used for senior executive compensation purposes and disclosed in the Statement of Executive Compensation later in this Circular.
Based on this approach and on such annual review, the Board, on the recommendation of the NCGC, has approved an increase in the annual retainer for Emera Directors by $22,500 per annum, all payable in cash, for a total annual Director retainer of $275,000, effective January 1, 2024.
The Board, on the recommendation of the NCGC, also approved an increase to the annual retainer for the Chair of the Board by $25,000, $12,500 of such increase payable in cash and $12,500 payable in DSUs, for a total annual Board Chair retainer of $475,000. In addition, the Board, on the recommendation of the NCGC, also approved a $2,500 increase to the annual Committee Chair retainer for each of the MRCC, NCGC, HSEC and RSC, for a total annual Committee Chair retainer of $25,000 each. There was no increase in the Audit Committee Chairs annual retainer. The increases to the annual Board Chair retainer and the annual Committee Chair retainers for the MRCC, NCGC, HSEC and RSC were effective January 1, 2024.
Effective January 1, 2024 the rates of compensation for Emera Directors are as follows:
Annual retainers for Directors in 2024 |
Cash amount ($) | DSUs ($) | Total ($) | |||||||||
Chairs retainer |
237,500 | 237,500 | 475,000 | |||||||||
Directors retainer |
115,000 | 160,000 | 275,000 | |||||||||
Audit Committee Chairs retainer |
27,500 | N/A | 27,500 | |||||||||
Audit Committee members retainer |
12,500 | N/A | 12,500 | |||||||||
Management Resources and Compensation Committee Chairs retainer |
25,000 | N/A | 25,000 | |||||||||
Management Resources and Compensation Committee members retainer |
10,500 | N/A | 10,500 | |||||||||
Nominating and Corporate Governance Committee Chairs retainer |
25,000 | N/A | 25,000 | |||||||||
Nominating and Corporate Governance Committee members retainer |
10,500 | N/A | 10,500 | |||||||||
Health, Safety and Environment Committee Chairs retainer |
25,000 | N/A | 25,000 | |||||||||
Health, Safety and Environment Committee members retainer |
10,500 | N/A | 10,500 | |||||||||
Risk and Sustainability Committee Chairs retainer |
25,000 | N/A | 25,000 | |||||||||
Risk and Sustainability Committee members retainer |
10,500 | N/A | 10,500 |
DIRECTOR SHARE OWNERSHIP GUIDELINE
Director common share and DSU ownership is viewed by Emera as an important means of enhancing the alignment of Director and shareholder interests. Under Emeras Director Share Ownership Guideline, each Director must own three times the total cash and equity-based annual Board retainer in Emera common shares or DSUs, or a combination of the two. New Directors must meet the ownership requirement of the Share Ownership Guideline within three years of joining the Board and are required to take 100 per cent of their compensation in DSUs until they have met the Director Share Ownership Guideline (Directors appointed before November 2021 have five years to meet the guideline).
Based on the annual cash ($115,000) and equity-based ($160,000) retainer compensation in effect for Emera Directors as of January 1, 2024 as described earlier this Circular, each Director must own Emera shares or DSUs, or a combination of the two, worth $825,000. The ownership requirement for the Chair of the Board, based on the Chairs annual cash ($237,500) and equity- based ($237,500) retainer compensation in effect as of January 1, 2024, as described above, is $1,425,000.
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The table below shows each Director nominees equity ownership as at December 31, 2023 and their holdings for the previous year, except Mr. Balfour because he is required to meet the share ownership requirements for executive officers (see Executive Share Ownership Requirements and Anti-Hedging Policy in the Statement of Executive Compensation in this Circular). All of Emeras Director nominees are in compliance with the Director Share Ownership Guideline.
Director Nominee |
Total common shares |
Total DSUs | Value at December 31, 2023 (1) |
Multiple of 2024 annual retainer |
Share Ownership Requirement ( 2) |
Year to meet share ownership requirement |
||||||||||||||||||
Scott Balfour (3) |
| | | | | | ||||||||||||||||||
James Bertram |
14,170 | 31,473 | 2,295,850 | 8.3x | 3x | Achieved | ||||||||||||||||||
Henry Demone |
9,062 | 43,145 | 2,625,990 | 9.5x | 3x | Achieved | ||||||||||||||||||
Paula Gold-Williams |
Nil | 11,204 | 563,549 | 2x | 3x | February 2025 | ||||||||||||||||||
Kent Harvey |
Nil | 26,166 | 1,316,130 | 4.7x | 3x | Achieved | ||||||||||||||||||
Lynn Loewen |
4,490 | 62,687 | 3,378,994 | 12.2x | 3x | Achieved | ||||||||||||||||||
Brian Porter (4) |
10,000 | Nil | 503,000 | 1.8x | 3x | March 2027 | ||||||||||||||||||
Ian Robertson |
32,600 | 9,757 | 2,130,552 | 7.7x | 3x | Achieved | ||||||||||||||||||
Jackie Sheppard (Chair) |
11,947 | 130,221 | 7,151,066 | 15x | 3x | Achieved | ||||||||||||||||||
Karen Sheriff |
1,000 | 15,263 | 818,029 | 2.9x | 3x | February 2026 | ||||||||||||||||||
Jochen Tilk |
Nil | 29,431 | 1,480,356 | 5.3x | 3x | Achieved |
(1) | The payout or market value of common shares/DSUs is based on the Emera common share closing price of $50.30 as of December 29, 2023. |
(2) | Under Emeras Director Share Ownership Guideline, a Director must own three times the total cash and equity-based annual Director retainer in Emera common shares or DSUs, or a combination of the two. |
(3) | Mr. Balfour is subject to the share ownership requirements for executive officers (see Executive Share Ownership Requirements and Anti-Hedging Policy in the Statement of Executive Compensation in this Circular). |
(4) | Mr. Porter joined the Board in March 2024 and at that time owned 10,000 common shares of Emera. He has until March 2027 to meet the share ownership guideline. |
DIRECTORS ARE INCREASING THEIR SHARE/DSU OWNERSHIP OVER TIME
By virtue of the compensation payable in DSUs, more than 58 per cent of the annual retainer for Emera Directors will be paid in DSUs, which mirrors the value of Emera common shares. The Directors increase their DSU ownership by at least $160,000 per annum. Most of the Director nominees have elected to receive DSUs in lieu of the cash component of the compensation they would otherwise be entitled to as Emera Directors.
DIRECTORS DSU PLAN
Under the Directors Deferred Share Unit and Share Purchase Plan (the Directors DSU Plan), non-employee Directors may elect to receive all or any portion of their cash compensation in DSUs in lieu of that cash compensation, subject to the requirement to receive a minimum portion of their annual retainer in DSUs and subject to the Emera Director Share Ownership Guideline.
Directors fees are paid on a quarterly basis, at which time, the applicable amount is converted to DSUs. The number of DSUs to be credited is determined by dividing: (a) the quarterly portion of the Directors annual fee that the Director is required to receive in DSUs, together with the portion the Director elected to be paid in DSUs by (b) the fair market value of an Emera common share on the last trading day of the preceding calendar year, with fractions computed to three decimal places.
A DSU is a unit that has a value based upon the value of one Emera common share. When a dividend is paid on Emeras common shares, the Directors 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 Directors 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.
To further encourage Directors to acquire Emera shares, the Directors DSU Plan was amended in September 2022 to provide them with the opportunity to elect to receive market-purchased shares. Under the Directors DSU Plan, Directors may elect in advance to receive DSUs, common shares of Emera, or a combination of DSUs and shares, in lieu of their cash compensation. Any portion of a Directors fees that the Director elects to receive in the form of shares would not be deferred compensation (as is the case when a Director receives fees in the form of DSUs) and, therefore, would be subject to applicable income tax withholdings. Thus, compensation net of tax withholdings would be used to purchase shares. Under the Directors DSU Plan, Directors may request that Company shares acquired on their behalf be (i) sold or (ii) withdrawn from the revised Directors DSU Plan and
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delivered in accordance with such Directors instructions. Absent special instructions, the custodian would hold the shares in an account maintained by the custodian for the benefit of the Director. Any dividends earned on such shares would be automatically reinvested in shares acquired on the market and credited to the Directors account.
2.9 | Additional Information |
Additional information relating to the Company may be found on the System for Electronic Document Analysis and Retrieval + (SEDAR+) at www.sedarplus.com. The Companys financial information is contained in its comparative financial statements and managements discussion and analysis for the financial year ended December 31, 2023.
Documents and websites referenced herein are not incorporated by reference into this Circular unless the incorporation by reference is explicit. References to our website address in this Circular are intended to be inactive textual references only.
For copies of the Companys financial statements and managements 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: 902-428-6996; Facsimile: 902-428-6171; email: Brian.Curry@emera.com.
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3. Executive Compensation
Emeras approach to executive compensation is supported by strong governance and robust risk management, and designed to achieve results, drive growth and deliver value to customers and shareholders. Recruiting and retaining top talent is fundamental to Emeras success.
IN THIS SECTION | 3.1 | MESSAGE FROM THE MANAGEMENT RESOURCES AND COMPENSATION COMMITTEE TO OUR SHAREHOLDERS | 66 | |||
3.2 | STATEMENT OF EXECUTIVE COMPENSATION | 68 | ||||
3.3 | COMPENSATION DISCUSSION AND ANALYSIS | 74 | ||||
3.4 | PERFORMANCE GRAPH | 93 | ||||
3.5 | NEO SUMMARY COMPENSATION TABLE | 95 |
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3.1 Message from the Management Resources and Compensation Committee to Our Shareholders
Dear Shareholder,
In 2023, the Emera team made significant progress in advancing the corporate strategy and delivering shareholder value.
All aspects of Emeras compensation programs, including executive compensation, are overseen by the Management Resources and Compensation Committee of the Board (the Committee or MRCC). In this Circular, we are pleased to provide an overview of our approach to executive compensation, the Boards assessment of Emeras 2023 performance, and our decisions relating to executive compensation.
Emeras approach to executive compensation is designed to align pay with performance. We do this by ensuring a significant portion of the compensation we pay to executives is directly linked to the achievement of corporate objectives and share price performance. Additionally, our share ownership guidelines require our executives to hold significant equity (or equity equivalent) in Emera. The MRCC carefully assesses performance measures and targets to ensure they reflect Emeras values and strategic priorities and recommends changes to the Board as appropriate. The targets must be achieved within the principles of prudent risk management, good corporate governance and compliance with relevant regulations. Guided by these principles, along with input from other members of the Board and independent consultants, the MRCC oversees the establishment of Emeras performance goals, which are based on Board-approved financial objectives and budgets. The MRCC also assesses Emeras executive compensation programs, including short- and long-term incentive payouts for the executive team.
2023 COMPENSATION
Our compensation philosophy is guided by the median level of compensation paid by our peer group, which is made up of companies of a similar size and scope as Emera. In addition to market competitive data, the Committee considers experience, uniqueness of responsibilities and performance of the Named Executive Officers (NEOs) in setting the level of target compensation.
At the end of 2022, the Committee reviewed benchmarking analyses from both Hugessen Consulting Inc. (Hugessen), the Boards independent compensation advisor, and Mercer (Canada) Limited (Mercer), managements external compensation advisor, using the Companys peer comparator group.
Based on the comparative positioning of Emeras target compensation to market, the Committee is satisfied that our NEOs are compensated competitively and in alignment with our compensation philosophy. The Committee will continue to monitor market trends to maintain our competitive positioning and our ability to attract the skills and talent required to operate our assets and deliver on our strategy.
The Committee also conducted its annual risk assessment to identify potential risks associated with Emeras compensation design and policies. The assessment concluded that there are no material risks associated with Emeras compensation programs and the Company has an appropriate system of checks and balances to mitigate the level of risk undertaken by management.
Recognizing Emeras performance against objectives established for the 2023 Emera Corporate Scorecard, the Board approved an annual Short-term Incentive Plan payout of 115.5 per cent of target for the NEOs. A full description of the 2023 Scorecard metrics and results is provided in 2023 Short-Term Incentive Results on page 80.
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Our 2023 Long-term Incentive Program, which consisted of performance share units (PSUs), restricted share units (RSUs) and stock options, is also closely aligned with our performance objectives. PSUs are linked to performance metrics that are measured over a three-year period. The 2021 PSU grant, which had a performance period from January 1, 2021 to December 31, 2023, measured Emeras growth in adjusted earnings per share for compensation purposes (compensation EPS) and adjusted operating cash flow, pre-working capital for compensation purposes (compensation cash flow, pre-working capital) (1). It also measured Emeras Total Shareholder Return (TSR) against that of the S&P/TSX Capped Utilities Index. Emeras compensation EPS growth performance fell just below target level but compensation cash flow, pre-working capital exceeded stretch, which resulted in a performance factor of 115 per cent. A full description of the 2021 PSU grant result is provided on page 87.
The Committee engaged Hugessen 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. Balfour from 2019 to 2023 and compared the investment returns experienced by shareholders over the same period. The analysis included both realized pay (consisting of amounts paid) and realizable pay (consisting of the value of any outstanding equity-based awards). The analysis concluded there was appropriate alignment between the President and CEOs realized/realizable pay and shareholders return on investment experience over the long term. Please see Total Shareholder Return and President and CEO Compensation on page 94 for more information on the analysis.
Based on Emeras performance in 2023 and the impact of that performance on the compensation paid to our executives, we remain confident that our incentive plans and resulting payouts are closely aligned with the interests of our shareholders.
SHAREHOLDER FEEDBACK
At our 2023 Annual Meeting, we held our annual Say on Pay advisory vote allowing shareholders to indicate whether they agree with Emeras compensation practices and policies. Shareholders voted 94.46 per cent in favour of our approach to executive compensation. At this years Annual Meeting, we will again be presenting a Say on Pay non-binding advisory resolution. As part of our continued commitment to shareholder engagement, it is important for us to receive direct feedback from our shareholders and to 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.
As always, we welcome your thoughts on our compensation programs and results, which are described in more detail in the Statement of Executive Compensation that follows. We encourage you to take part in our Say on Pay vote and we welcome your questions and feedback, which can be provided directly to the Chair of the Committee or the Chair of the Board by mailing (through regular mail or other means of delivery) to:
Attention: Chair of the MRCC | Attention: Chair of the Board | |
P.O. Box 910, Halifax, Nova Scotia B3J 2W5 | P.O. Box 910, Halifax, Nova Scotia B3J 2W5 | |
in a sealed envelope marked Private and Confidential Attention, Chair of the MRCC of Emera Inc. | in a sealed envelope marked Private and Confidential Attention, Chair of the Board of Directors of Emera Inc. |
Henry Demone | James Bertram | Karen Sheriff | Jochen Tilk | |||
Director and Chair of the | Director and Member of the | Director and Member of the | Director and Member of the | |||
Management Resources and | Management Resources and | Management Resources and | Management Resources and | |||
Compensation Committee | Compensation Committee | Compensation Committee | Compensation Committee |
(1) | Compensation EPS and compensation cash flow, pre-working capital are non-GAAP measures and do not have standardized meaning under United States Generally Accepted Accounting Principles (USGAAP). A reconciliation of these non-GAAP measures to the nearest GAAP measures is discussed on page 88. |
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3.2 Statement of Executive Compensation
Emeras approach to executive compensation is designed to achieve results, drive growth and deliver value to customers and shareholders. We are committed to:
| aligning the financial interests of executives with Emeras broader strategic and business interests and the related interests of Emeras shareholders, customers and other stakeholders; |
| rewarding Emeras executives for sustained growth in shareholder value; |
| paying competitively with our North American peers; |
| balancing short- and long-term incentive plans that reflect our pay-for-performance philosophy; and |
| managing risk through good governance. |
MARKET COMPETITIVENESS
Emera benchmarks executive compensation to ensure the Company pays competitively in the markets where it operates, and to motivate, attract and retain high-quality talent. Emeras executive compensation program is designed to generally provide total target compensation at the median of compensation paid by comparable companies whose operations are of a similar size and scope as Emera. Pay positioning, in some specific cases, may be above or below the median based on experience, uniqueness of responsibilities, performance and succession planning. Total target compensation for senior management, including the NEOs, is comprised of base salary, target short-term incentive and target long-term incentives linked to creating shareholder value.
PAY-FOR-PERFORMANCE PHILOSOPHY
A core principle of Emeras executive compensation philosophy is that a significant portion of executive compensation is at risk and linked to share price performance and the achievement of performance objectives that measure whether shareholders are receiving appropriate return for their investment. The at-risk components include both short- and long-term incentives, which establish measurable financial, organizational, climate, environmental, social and governance objectives, including safety that, if achieved, add value to the Company.
The incentive compensation plans are designed to pay greater amounts for superior performance and lesser amounts if target performance is not achieved. Emera must achieve a threshold level of performance for any payment against a particular objective or there is no payment against that objective. The Board Chair, in collaboration with the MRCC and the Board as a whole, assesses the performance of the President and CEO. Executives performance against those objectives is measured and rated by the President and CEO with a recommendation to the MRCC, which in turn discusses the assessments with the Board of Directors for approval.
Generally, the at-risk compensation component of total compensation increases in conjunction with the individual executives level of responsibility. The Company considers many factors when developing the incentive plans, including current compensation trends, plan costs (including maximum payout values), expected value to be delivered to participants, and analysis of threshold, target and stretch payouts. Both short- and long-term incentive plans are modelled using historical and prospective performance scenarios. This stress testing provides the MRCC and the Board with reasonable assurance that the plan payouts will be appropriately 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 remain appropriate or require any changes.
The MRCC and Board reserve the right to exercise discretion in adjusting compensation payouts up or down to align with Company results, which may include refraining from paying out any amounts under the incentive compensation plans where circumstances warrant.
The MRCC has previously approved a set of guiding principles to govern when discretion is applied to ensure consistency and fairness when adjustments are made to incentive compensation. These guidelines are detailed on page 70.
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COMPENSATION PROGRAM
Emeras compensation program includes the following components:
Base Salary (page 80): Salaries are benchmarked against companies of similar size and scope as Emera or the respective affiliate and are set to reflect the degree of special skills and knowledge required now and in the future for the position and the performance and contribution of the individual. |
Short-term Incentive Plan (page 80): Short-term incentive objectives are set forth in scorecards and consist of key annual objectives linked to the Companys corporate strategy. These scorecards establish measurable financial, organizational, environment, social and governance objectives including safety that, if achieved, add value to the Company. |
Long-term Incentive Program (page 85): Consists of performance share units (PSUs), restricted share units (RSUs) and stock options. Levels are determined based on competitive benchmarking data and the degree of the executives 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 97): The Pension Plan consists of either defined benefit or defined contribution components and a supplemental employee retirement plan, all of which are governed by a pension oversight governance framework. |
Other Executive Benefits (page 91): The Company offers market competitive non-cash compensation components such as group benefits, vacation, wellness incentives and an employee common share purchase plan. |
Management Resources and Compensation Committee
The Board has assigned responsibility to the MRCC to review, recommend and oversee the determination of the compensation for Emeras executive officers and the administration of all the Companys executive compensation plans and programs. Current members of the MRCC are:
Mr. Henry Demone (Chair)
Mr. James Bertram
Ms. Karen Sheriff
Mr. Jochen Tilk
All members of the MRCC are independent Directors. Each member of the MRCC has experience with human resources issues and compensation matters. More detailed information on each members qualifications and experience is contained in the section entitled Director Nominees earlier in this Circular.
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The MRCC considers best practices in determining and monitoring executive compensation as discussed in this Circular. We are guided by the following key practices, which we believe promote good governance and serve the interests of our shareholders:
What we do |
Align the Companys compensation programs with its corporate strategy, using financial and non-financial performance metrics that support both short- and long-term strategic goals. |
Perform an annual risk assessment to identify risks associated with our pay structure. |
Retain an independent compensation advisor for the MRCC that does not provide any services directly to management. |
Allow for the reduction or withholding of payouts and the inclusion of threshold performance hurdles under the short-term and equity-based incentive plans for results below expectations, at the MRCC and Boards discretion. |
Provide shareholders with the opportunity to vote on a Say on Pay resolution at the Companys Annual Meeting, which allows shareholders to indicate whether they agree with Emeras compensation practices and policies (94.46 per cent of votes cast last year were in favour of the Companys approach). |
Use double-trigger change of control agreements. |
Test compensation awards for appropriate alignment between pay and performance under several different outcome scenarios. |
Oversee the compilation and review of the detailed information on those companies used in the Companys 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 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 Companys risk profile to discourage the taking of short-term or excessive risks. |
Conduct pay equity analyses to help ensure the Companys hiring and pay practices promote equity. |
Have a pension oversight governance framework in place for pension benefits. |
Monitor the ratio of the Companys NEOs total compensation to the median employees 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 five years, factoring in long-term incentive payouts and changes in value. |
Translate United States dollar (USD) earnings to Canadian dollar (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 Companys performance results against its targets. |
Provide guidance and oversee the Companys extensive succession planning program, including all major components, such as routine efforts to identify successor readiness over one-, three-, and five-year forward-looking employee development horizons. |
What we dont do |
Allow for the repricing or backdating of stock options. |
Allow the payment of dividends on share awards prior to vesting. |
Count unvested awards, including PSUs and RSUs, 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 Companys pension plan or supplemental employee retirement plan. |
Compensate executives for sitting on or chairing the Boards of any of Emeras operating companies. |
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MRCC GOVERNANCE
The MRCC is responsible for reviewing the alignment of Emeras compensation programs, including incentive pay programs, with Emeras strategic plans, performance and risk management principles. The Committee annually reviews compensation for the President and CEO and senior management of the Company. The MRCC oversees the administration of the incentive plans providing for the award of short-term incentives, stock options, PSUs, RSUs and deferred share units (DSUs) in accordance with the provisions of the respective plans.
The Committee reviews, and recommends to the Board of Directors, compensation policies and processes, any new incentive plan and the equity compensation plans and any changes to such plans.
The Board Chair specifically discusses the President and CEOs performance with each Director individually, and as a group, and provides feedback to the MRCC, the Board and the President and CEO on at least an annual basis. In addition, the CEO reports, and the Committee reviews, the progress toward annual objectives at every Board meeting.
RISK MANAGEMENT AND COMPENSATION
As part of the Board and MRCCs oversight responsibilities for the design and administration of Emeras executive compensation programs, the MRCC identifies and discusses design features or processes that may potentially represent conflicts of interest or inducements for unnecessary or excessive risk-taking by senior executives.
The MRCC also regularly monitors industry trends with respect to risk management and conducts an annual risk assessment in consultation with an external compensation consultant. Emeras compensation programs and policies are designed to incorporate the Companys view on appropriate risk, as demonstrated by the elements shown below, which are discussed in greater detail in the sections that follow:
The Company regularly reviews its executive compensation programs with third-party compensation advisors to confirm the programs continue to align with shareholder and stakeholder interests, comply with regulatory requirements, and are consistent with sound principles of risk management and governance. The MRCC retains an independent compensation advisor that does not provide any services directly to management. |
The Company has a pay-for-performance philosophy and the mix of short- and long-term programs assists in mitigating excessive risk-taking. |
Vesting requirements, stress testing of potential payouts, clawback provisions, an anti-hedging policy and share ownership requirements are part of the Companys overall plan designed to mitigate risk. For more information, please see the Executive Share Ownership Requirements and Anti-Hedging Policy section on page 92. |
The Companys compensation governance structure involves the Board, the MRCC, the MRCCs external compensation advisor, management, and managements external compensation advisors. |
All members of the MRCC have the necessary background and expertise in human resources issues and compensation matters to fulfil their obligations to the Board and to shareholders. |
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Annual Compensation Risk Assessment
In 2023, the MRCC conducted its annual compensation risk review of our executive compensation programs and policies. To assist in the review, management engaged Mercer to evaluate their previous years comprehensive risk assessment for any material changes over the course of the year. Mercer again concluded that Emera has risk mitigation policies in place that are aligned with market best practices and did not identify any material risks arising from Emeras 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 Companys shareholders; |
| The use of multiple performance measures in the incentive plans (including non-financial measures) helps to avoid undue focus on any one particular metric; |
| The Short-term Incentive Plan focuses on growth of annual earnings and cash flow, but caps incentive payouts in a manner consistent with market practice, thereby reducing risk; |
| Risks associated with the Long-term Incentive Plan are mitigated by annual grants (versus front-loading grants) of PSUs, RSUs and stock options. Risks that incentive plans may incentivize activities that are inconsistent with Emeras strategy are mitigated by choosing metrics aligned with key areas of financial and strategic performance; |
| The MRCC and Boards discretion to reduce or withhold payment under the short-term and equity-based incentive plans for results below expectations decreases the risks associated with those plans; |
| Emeras 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 Companys 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 and promote a continued vested interest in the Company post-retirement; |
| The clawback policy contributes to the Companys risk mitigation efforts and 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 executives 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 Companys 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 situation 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 Emeras compensation programs do not pose a material risk to the Company because an appropriate system of checks and balances is in place to mitigate the level of risk undertaken by management. The MRCC satisfies itself as to the adequacy of the information it receives regarding risk, the independence of the risk assessment, and the reporting of financial results on which certain important compensation decisions (such as incentive payouts) are based.
The MRCC and Board will continue to review the relationship between enterprise risk and the Companys executive compensation plans and policies to confirm they continue to be optimally aligned with shareholder interests while maintaining an acceptable level of risk exposure.
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SUCCESSION PLANNING AND LEADERSHIP DEVELOPMENT
At Emera, succession planning is a dynamic, ongoing process of identifying, assessing and developing leadership competencies and business skills. The purpose is to confirm the Companys capacity to meet future strategic objectives and to replenish critical organizational roles over time.
The MRCC assists the Board in the succession planning process for the President and CEO and has responsibility for overseeing succession planning for senior management of the Company and its operating companies. The Board also has responsibility for approving the appointment of the Companys officers.
As part of Emeras comprehensive succession planning process, management and the MRCC review, on an annual basis, the detailed management succession and development plans, and potential candidates for CEO and senior management positions throughout the Company and its operating companies. The Committee oversees the management succession planning process and developmental strategy, which includes assessments of the senior leadership at all operating companies to leverage the entire talent pool across Emera. The Board receives a related progress report from the CEO at every Board meeting during the in-camera session. In addition, the process also involves an annual discussion between the Chair and every member of the Board. The Company also considers external candidates when filling executive roles.
The succession planning process includes the identification of successors for all executive roles on a temporary or urgent basis in the event of an unexpected vacancy. This helps to ensure that any impact on the Companys operations is minimized until such time that a permanent successor is in place.
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 and the leadership team related to identified core leadership capabilities. Personal development plans and overall Company leadership development programs are in place for both existing and potential leaders. The Company focuses on ensuring challenging work assignments are offered, secondments to operating companies are made where appropriate, regular leadership development training occurs and mentors are assigned, where beneficial.
Emera will continue these focused efforts to build leadership capacity throughout the organization in support of its long-term growth strategy.
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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 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. In addition, Hugessen advises the MRCC on policy recommendations made by management and reviews and provides commentary on the Companys Statement of Executive Compensation. As independent advisors to the MRCC, Hugessen does not provide any professional services to management.
Recently, the MRCC received proposals from Committee consultants, including Hugessen. Following this process, Hugessens engagement was renewed.
The MRCC:
| Annually reviews the advisors performance and fees. |
| With input from Company management and the advisor, 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, ensures the advisor provides an outline of the scope of work and related fees, and the MRCC Chair must provide written pre-approval. |
| Does not approve any work that, in its view, could compromise the advisors independence in serving the MRCC. |
In addition to the MRCCs compensation advisor, Emera engaged the services of Mercer and TELUS Health in 2023 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 TELUS Health, 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 2022 and 2023.
2023 | 2022 | |||||||||||||||
Advisor |
Executive Compensation- Related Fees ($) |
All Other Fees ($) | Executive Compensation- Related Fees ($) |
All Other Fees ($) | ||||||||||||
Hugessen Consulting Inc. |
143,193 | Nil | 128,655 | Nil | ||||||||||||
TELUS Health |
Nil | 109,102 | Nil | 75,415 | ||||||||||||
Mercer (Canada) Limited (1) |
Nil | 251,007 | Nil | 200,285 |
(1) | Mercer (Canada) Limited was retained by the Nominating and Corporate Governance Committee in 2022 and 2023 to review Directors compensation; the fees for that review are included in the amounts shown. |
3.3 | 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 operating companies, as defined by Canadian securities legislation:
| Scott Balfour, President and Chief Executive Officer, Emera Inc. (President and CEO); |
| Greg Blunden, Chief Financial Officer, Emera Inc. (CFO); |
| Archibald Collins, President and Chief Executive Officer, Tampa Electric Company; |
| Karen Hutt, Executive Vice President (EVP), Business Development and Strategy, Emera Inc.; and |
| Bruce Marchand, Chief Risk and Sustainability Officer, Emera Inc. |
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Scott Balfour, President and Chief Executive Officer, Emera Inc.
Scott Balfour became President and CEO of Emera in 2018. He joined the company as Chief Financial Officer in 2012 and became Chief Operating Officer in 2016. Since joining Emera, Scott has been instrumental in driving the companys growth. He played a lead role in the $10.4B USD acquisition of TECO Energy in 2016 at the time, one of Canadas largest cross-border mergers and acquisition transactions. Scott is leading the team in executing on the companys long-standing strategy to safely deliver cleaner, affordable and reliable energy to customers. Under his leadership, the team continues to drive growth and create significant value for customers, shareholders and communities. In May 2021, Scott was named CEO of the Year by Atlantic Business Magazine. After beginning his career in commercial and corporate banking, Scott spent nearly two decades in Canadas finance and construction sectors. First as CFO, then as President, Scott led the growth of the Aecon Group from a $60 million to a $2.8 billion company and one of Canadas largest publicly traded construction firms. Scott is a director of several of Emeras operating companies including being Chair of Tampa Electric, Peoples Gas and Nova Scotia Power. He is a board member of the Edison Electric Institute and the Business Council of Canada. He received a Bachelor of Business Administration (Honours) from Wilfrid Laurier University and earned a Master of Business Administration from the Richard Ivey School of Business, University of Western Ontario.
Greg Blunden, Chief Financial Officer, Emera Inc.
Greg Blunden was appointed CFO of Emera Inc. in March 2016. He joined Emera in 2000 and has held financial leadership roles at Emera Inc., Emera Maine and Nova Scotia Power. Greg has valuable experience and industry insight into all aspects of our business such as corporate finance, business development, utility operations, customer service, renewable energy and regulatory policy. Previously, he was Emeras Vice President, Corporate Strategy & Planning, and before that he held the position of EVP, Customer, Business & Financial Services at Nova Scotia Power. Greg is a graduate of Mount Allison University. He is a Chartered Professional Accountant and in 2019 he was awarded the designation of Fellow Chartered Professional Accountant (FCPA).
Archibald Collins, President and Chief Executive Officer, Tampa Electric Company
Archie Collins was appointed President and CEO of Tampa Electric in May 2021. He began his career in the energy sector with Nova Scotia Power in 1990. Since then, he has held increasingly senior leadership roles within NSP, Emera Energy, Emera Caribbean and Tampa Electric. Archie has served as President and Chief Operating Officer of Emera Caribbean, President and CEO of Grand Bahama Power, Executive Vice President Commercial Operations with Emera Energy, and Chief Operating Officer of Tampa Electric. Archie is a professional chemical engineer and holds a Diploma in Engineering from St. Francis Xavier University and a Bachelor of Chemical Engineering from Dalhousie University. He is a member of the Florida Council of 100 and serves on the boards of the Florida Chamber of Commerce, the Tampa Bay Economic Development Committee, the Tampa Medical and Research District Advisory Committee, the Association of Edison Illuminating Companies and the Tampa Theatre. He also chaired the American Heart Associations 2023 Heart Walk in Tampa.
Karen Hutt, Executive Vice President, Business Development and Strategy, Emera Inc.
Karen Hutt leads Emeras business development and strategy efforts, playing a lead role in the companys next growth phase. Karen also has executive oversight of Emeras Corporate Affairs function. Karen joined Emera in 2021 and prior to her current role, served as President and Chief Executive Officer of Nova Scotia Power Inc. a role she held from August 2016 until October 2019. Previously, as Emeras Vice President, Mergers and Acquisitions, Karen was part of the team that executed the TECO Energy transaction a transformational deal that doubled the size of Emera. Prior to that, she served as Emera Energys Executive Vice President, Commercial, and President, Northeast Wind. An active supporter of the local community, Karen currently serves on the Acadia Board of Governors. She is a past Chair of the IWK Health Centre in Halifax and also served as a Trustee of the IWK Foundation Board. She is Past-Chair of the Junior Achievement of Nova Scotia Board of Directors. Karen holds degrees from Acadia University and Mount Saint Vincent University and has an ICD.D designation from the Institute of Corporate Directors.
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Bruce Marchand, Chief Risk and Sustainability Officer, Emera Inc.
After a successful legal career in private practice, Bruce joined Emera as Chief Legal Officer in 2012. His role was expanded in 2014 when he was named Chief Legal & Compliance Officer. In July 2022, Bruce was appointed Chief Risk & Sustainability Officer, adding to his enterprise risk management role the responsibility for Emera-wide Sustainability. Bruce chairs Emeras Mandatory Sustainability Disclosure Task Force. In 2023, Bruce was appointed to the Canadian Sustainability Standards Board. Bruce has chaired or otherwise been involved in a number of local and regional non-profit boards and fundraising initiatives, including the Atlantic Economic Council, QEII Health Sciences Centre Foundation, Canadian Cancer Society, Junior Achievement, the Mental Health Foundation of Nova Scotia, the United Way and March of Dimes. Bruce earned a bachelors degree and University Medal in Economics from Acadia University and is a graduate of the Schulich School of Law at Dalhousie University. He is a long-standing member of the Nova Scotia Barristers Society and the Canadian Bar Association.
The total target compensation for each NEO in 2023 is outlined below:
Name |
Base salary ($) | Short-term incentive at target (% of base salary) |
Short-term incentive at target ($) |
Long-term incentive at target (% of base salary) |
Long-term incentive at target ($) |
Total target compensation ($) |
||||||||||||||||||
Scott Balfour |
1,133,000 | 100 | 1,133,000 | 515 | 5,834,950 | 8,100,950 | ||||||||||||||||||
Greg Blunden |
620,000 | 80 | 496,000 | 220 | 1,364,000 | 2,480,000 | ||||||||||||||||||
Archibald Collins |
600,000 | 80 | 480,000 | 150 | 900,000 | 1,980,000 | ||||||||||||||||||
Karen Hutt |
535,000 | 70 | 374,500 | 180 | 963,000 | 1,872,500 | ||||||||||||||||||
Bruce Marchand |
545,000 | 70 | 381,500 | 160 | 872,000 | 1,798,500 |
The following charts show the percentage weighting of each component of the total target compensation for the NEOs. In keeping with the Companys pay-for-performance philosophy, the 2023 compensation plan design resulted in 86 per cent at-risk pay for our President and CEO and an average for the five NEOs of 74 per cent.
Figures in charts have been rounded to the nearest percentage.
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COMPENSATION PROCESS
Benchmarking Data
The MRCC is responsible for annually reviewing the composition and use of comparator groups to assist in determining the compensation recommendations for the Companys senior officers, including the President and CEO and other NEOs. The recommendations are then brought to the Board for approval. The MRCC undertakes periodic reviews of compensation design and total compensation opportunities for the senior management team, which helps ensure the programs are current and that they are fair comparisons for particular roles, recognizing varying responsibility and scope of executive positions within Emera and its operating companies.
Emera management engages the services of Mercer 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 Companys compensation programs.
A complete benchmarking review takes place annually, and the scope of services includes competitive market studies of senior executive compensation levels, review and observations of current executive compensation philosophy, policies and practices, and a review of pay and performance comparators. A review of the Companys benchmarking peer group was done at the end of 2022. Following the de-listing of former peer Inter Pipeline, the MRCC approved Northland Power as a replacement given its comparable size and industry relevance.
The Companys comparator group for senior executives consists of two subgroups: (1) a Canadian group of companies in the Canadian energy, utility and general industry sectors; and (2) a US group of US energy and utility companies. It consists of the following companies:
![]() |
Canadian comparators | US comparators | ||
Energy & Utility Industry Algonquin Power & Utilities Corp. AltaGas Ltd. ATCO Ltd. Fortis Inc. Hydro One Ltd. Keyera Corp. Northland Power Pembina Pipeline Corp. TC Energy Corp. TransAlta Corp.
General Industry Air Canada Canadian Pacific Railway Canadian Tire Corp. Ltd. Loblaw Companies Ltd. Nutrien Ltd. Restaurant Brands International LP Rogers Communications Inc. TELUS Corp. |
Energy & Utility Industry Alliant Energy Corp. Ameren Corp. Atmos Energy Corp. Avangrid Inc. Black Hills Corporation CenterPoint Energy, Inc. CMS Energy Corp. DTE Energy Company Evergy, Inc. Eversource Energy NiSource Inc. OGE Energy Corp. Pinnacle West Capital Corp. Sempra Energy UGI Corp. WEC Energy Group, Inc. |
The inclusion of US companies reflects that approximately 73 per cent of Emeras assets are US-based and approximately 70 per cent of Emeras revenues came from US operations in 2023. It also recognizes the talent market for the executive team and that most of Emeras 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. The Committee considers the corporate and geographical scope of each executives responsibilities when setting benchmark comparator groups. When benchmarking executives who are paid in Canadian dollars against roles that are paid in US dollars, the Company uses the five-year average exchange rate between Canada and the US to smooth out the impact of currency fluctuations.
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The following chart shows where Emera was positioned compared to the companies in both the Canadian and the US comparator groups based on selected key financial metrics market capitalization, total enterprise value, assets, revenues, and earnings before interest, taxes, depreciation and amortization (EBITDA).
Emera vs. Pay Benchmarking Comparator Groups
(1) | As at date of analysis, February 21, 2023. |
(2) | Last twelve months at December 31, 2022. |
Note: The above table was prepared by Hugessen Consulting Inc. using data from S&P Capital IQ.
In addition to using publicly disclosed compensation data from the companies in the comparator group, for additional comfort, the MRCC also considers executive compensation data from energy and services companies with similar revenues to Emera in Mercers Total Compensation Survey for the Energy Sector. In some cases, the MRCC may consider executive compensation data from general industry companies of similar size to Emera in Mercers Benchmark Database Survey.
With the assistance of Hugessen and Mercer, the Committee conducted a compensation benchmarking review of the executive team at the end of 2022 to set 2023 pay using the comparator group and survey data and undertook a review of the competitiveness and appropriateness of Emeras compensation programs. More details on the results of the review are provided in the next section.
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ANNUAL COMPENSATION REVIEW PROCESS
For each executive position, a range for base salary, target short-term incentive and target long-term incentive is established annually, using the benchmarking data along with other information on industry trends for positions of similar scope and responsibility.
The President and CEO conducts an annual performance assessment of each member of the executive leadership team, including the NEOs, which shapes the annual salary adjustment recommendations. Based on performance assessments and benchmarking data, the President and CEO then recommends total target compensation for each senior leader, including the NEOs (but excluding himself) to the MRCC for review and approval. With respect to the President and CEO, the Board conducts an annual performance assessment and the MRCC reviews benchmark data and other information on industry trends for positions of similar scope.
Following this process, the MRCC makes recommendations for total target compensation for the senior management team, including the President and CEO and the other NEOs, to the Board of Directors. As part of the annual compensation review process, the MRCC reviews emerging best practices and risk considerations.
At the end of 2022, both managements compensation advisor, Mercer, and the Committees compensation advisor, Hugessen, provided the results of their benchmarking reviews, which assisted in setting the compensation levels for the NEOs for 2023.
Mr. Balfour received a 3 per cent increase to base salary, resulting in 2023 total compensation of $8.1 million. In keeping with the Companys pay-for-performance approach, 86 per cent of Mr. Balfours compensation is allocated to his short- and long-term incentive targets, closely linking his compensation to the achievement of key objectives that advance Emeras corporate strategy and performance metrics that measure long-term shareholder value.
To reflect Mr. Blundens positioning against other CFOs and his continued growth and performance, he received a 3.3 per cent increase to base salary. In consideration of Mr. Collins strong performance and to align him to his peer group, he received a 16.0 per cent increase, including an increase to base salary and LTIP target. To maintain Ms. Hutts relative positioning against market and in recognition of her performance, Ms. Hutt received a 4.9 per cent increase to base salary. Based on Mr. Marchands change in role and his positioning against the updated benchmark, Mr. Marchands total compensation remained unchanged for 2023.
The compensation changes from 2022 to 2023 are summarized below. All changes were effective January 1, 2023:
Year | Base salary ($) |
Short-term incentive target (% of base salary) |
Long-term incentive target (% of base salary) |
Total target compensation (% increase) |
Proportion of compensation at risk (%) |
|||||||||||||||||||
Scott Balfour |
2022 | 1,100,000 | 100 | 515 | 3.00 | 86 | ||||||||||||||||||
2023 | 1,133,000 | 100 | 515 | |||||||||||||||||||||
Greg Blunden |
2022 | 600,000 | 80 | 220 | 3.33 | 75 | ||||||||||||||||||
2023 | 620,000 | 80 | 220 | |||||||||||||||||||||
Archibald Collins |
2022 | 535,000 | 80 | 140 | 15.65 | 70 | ||||||||||||||||||
2023 | 600,000 | 80 | 150 | |||||||||||||||||||||
Karen Hutt |
2022 | 510,000 | 70 | 180 | 4.90 | 71 | ||||||||||||||||||
2023 | 535,000 | 70 | 180 | |||||||||||||||||||||
Bruce Marchand |
2022 | 545,000 | 70 | 160 | 0.00 | 70 | ||||||||||||||||||
2023 | 545,000 | 70 | 160 |
As a result of the changes, the variable or at-risk component of the NEOs compensation averaged 74 per cent in 2023. The changes made to the compensation of the respective NEOs in 2023 are also reflected in the NEO Summary Compensation Table.
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ELEMENTS OF COMPENSATION
Base Salary
While the MRCC focuses on total compensation, base salary remains an important part of the overall compensation package the Company offers its executives. See the table above for 2023 base salary increases, which were intended to better align base salary positioning relative to the market.
Short-term Incentive Plan
The compensation awarded under the Short-term Incentive Plan links a portion of an executives 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 senior management, including the NEOs, are based on scorecard results with potential payouts ranging from 0 to 200 per cent of target.
Short-term incentive payouts for all NEOs are calculated based on results achieved through a corporate scorecard.
2023 Short-term Incentive Results
2023 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 2023. It was used to determine the short-term incentive payouts for our corporate-level NEOs, Mr. Balfour, Mr. Blunden, Ms. Hutt and Mr. Marchand. The short-term incentive payout for Mr. Collins was based on the Tampa Electric Corporate Scorecard discussed below.
The Emera Corporate Scorecard objectives were based on the Companys Business Plan for the year and include threshold, target and stretch performance measures for each objective. To reach target level performance, all threshold and target measures must be achieved, and to reach stretch level performance, all threshold, target and stretch measures must be achieved.
The following shows the elements and results of the Emera Corporate Scorecard for 2023.
Financial Measures (1) 70% Weighting
(1) | Percentage payouts, below or above target for financial measures, are interpolated on a scale between each level of performance (50 per cent for threshold, 100 per cent for target and capped at 200 per cent for stretch). |
(2) | Adjusted net income attributable to common shareholders for compensation purposes (compensation net income) and cash flow from operations for compensation purposes (compensation cash flow) are non-GAAP financial measures and do not have a standardized meaning as prescribed by USGAAP. Calculation of these measures and reconciliation to the nearest GAAP measures are discussed on page 82. |
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Safety, Environment, and People 30% Weighting
Safety (10% weighting)
Threshold Measures |
Target Measures |
Stretch Measures |
Highlights | |||
75% of corporate senior management team to complete a minimum of one Safety Observation or Safety Engagement every six months. |
50% reduction in consolidated High-Energy SIF (HSIF) plus SIF Prevention Program to be implemented and SIF concepts integrated into affiliate operational controls. | Achieve 20% reduction in consolidated Lost Time Injury (LTI) Frequency Rate compared to the five-year rolling average. | All threshold, target and stretch measures have been achieved.
We continued to build on our critical safety programs, and our senior management team showed its commitment by exceeding our goal on completing field level safety observations and engagements with our frontline employees.
We continued implementation of our Serious Injury and Fatality (SIF) prevention program across our operations and successfully reduced our HSIF events by 83%.
We reduced our lost-time injury frequency rate by 24% across Emera, our lowest rate ever. | |||
Safety Result: Stretch |
Payout: 20% |
Environment (10% weighting)
Threshold Measures |
Target Measures |
Stretch Measures |
Highlights | |||
Complete Phase 3 of Uncontrolled Releases Prevention initiative; Development of detailed Cority Release 2 training materials by Q2 and completion of Cority training by 90% of targeted Emera Inc. employees by year end. (Leaders Group + Occupational Health and Safety Committee). | Utilizing the Cority platform, implement an improved performance reporting system to management and key stakeholders that supports Management System requirements; Implementation of relevant Cority Release 2 functionality per affiliate implementation plans and achieve no significant events. |
Conduct gap analysis of Scope 3 Greenhouse Gases emissions inventory at Emera. | All threshold, target, and stretch measures have been achieved.
There were no significant environmental incidents.
A gap analysis of Scope 3 Greenhouse Gasses emission inventory was completed and presented to leadership. | |||
Environment Result:
Stretch |
Payout:
20% |
People (10% weighting)
Threshold Measures |
Target Measures |
Stretch Measures |
Highlights | |||
80% of leaders will create an action plan to implement with their teams following their attendance at a workshop on creating psychological safety. | 95% of Cyber Training Completed and 95% of employees have a career conversation with their leader and the results are captured. | An average monthly cybersecurity phish rate of 5% for Emera, following the removal of the best and worst month.
Ensure a diverse qualified candidate short list for external postings at a minimum of 75% of the time. |
All threshold, target, and stretch measures have been achieved.
We continued our DEI journey by providing a diverse qualified candidate short-list 88% of the time, surpassing our goal.
Psychologically safety was a focus for leaders, with 90.5% attending a workshop and producing an action plan for their teams. | |||
People Result: Stretch |
Payout: 20% |
Total 2023 Emera Corporate Scorecard Result: 115.5% |
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The financial targets reflected in the scorecard are linked to per share outcomes but are set at absolute levels to avoid the risk of incentive impacts influencing the timing of financing decisions within the year.
The compensation cash flow and compensation net income figures that are shown in the Emera corporate scorecard are adjusted for incentive purposes from the Companys reported figures. The Company considers the following general principles when determining whether it should adjust financial results for incentive plan purposes:
| The Company adjusts the reported figures for specific items the Company believes are significant, but not reflective of underlying operations in the period. |
| Incentive compensation should be directly linked to the performance of the core business and delivering on the plan of record. Meaningful accounting gains or losses are generally the result of strategically or financially driven transactions in which there has been direct involvement and support of the Board; therefore, the impacts of the transactions should typically be excluded from incentive compensation, except as noted below. The Company does not want its strategically or financially driven decisions to be influenced by compensation impacts. |
| The Company should, however, consider including all or some portion of the gain (positive impact) or loss (negative impact) if such gain or loss appropriately reflects the value creation or value destruction and overall performance of management in the decision or execution of the transaction leading to such gain or loss. |
| Perfect alignment of performance and compensation can be elusive from year to year. Therefore, the Board reserves the right to adjust incentive payouts in either direction to satisfy itself that there is close alignment between performance and compensation. |
The timing of fuel and storm cost recoveries had significant impacts on the Companys Compensation Cash Flow metric in the Emera corporate scorecard as well as the 2021 PSU grant. These unexpected costs will ultimately be recovered in subsequent years following established regulatory processes and incorporated into respective future budgets and targets. As such, the 2023 Compensation Cash Flow results have been adjusted to neutralize the impact of timing differences between when the fuel and storm costs are incurred and when they will be recovered. The table that follows shows the reconciliation between the reported and adjusted figures used in the Emera corporate scorecard. Adjustments in respect of the 2021 PSU grant are disclosed on page 88.
Compensation net income reconciliation (in millions $) |
2023 | |||
Reported net income attributable to common shareholders |
978 | |||
Less: Mark-to-market gain, after tax (1) |
(169 | ) | ||
Add: Adjustment to translate USD earnings to budgeted foreign exchange rate |
(22 | ) | ||
|
|
|||
Compensation net income |
787 | |||
|
|
Compensation cash flow reconciliation (in millions $) |
2023 | |||
Reported operating cash flow |
2,241 | |||
Add: Changes in non-cash working capital |
95 | |||
Add: Adjustment to translate USD earnings to budgeted foreign exchange rate |
(70 | ) | ||
Add: Adjustment for extraordinary fuel costs to be recovered in subsequent years |
127 | |||
Add: Adjustment for extraordinary storm costs to be recovered in subsequent years |
55 | |||
|
|
|||
Compensation cash flow |
2,448 | |||
|
|
(1) | Net of income tax expense of $68 million. |
While financial results fell below target, all measures related to safety, environment and people were achieved. In 2023, the lost- time injury frequency rate was reduced by 24 per cent across all operating companies, a record high for Emera.
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2023 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 Mr. Collins.
Financial Measures (1) 35% Weighting
Safety, People, Customer, Asset Management 65% Weighting
Safety (20% weighting)
Measures Included: | Highlights | |||
Proactive Incident Rate (PAIR) >250 and development of Personal Safety Plans.
High-risk reviews.
No High Energy Serious Injuries (HSIF) for the year.
All HSIF, Low-Energy Serious Injury or Fatality (LSIF) and Potential Serious Injury or Fatality (PSIF) incidents are investigated on a timely basis. |
All threshold and target measures were achieved. | |||
Safety Result: Target |
Payout: 20% |
People (15% weighting)
Measures Included: | Highlights | |||
Execution of DEI and pulse survey action plans.
Ensure a diverse, qualified candidate short list for external postings at Manager level and above >75% of the time.
Complete strategic workforce plan.
Completion and review of development plans for all management employees.
Achieve employee retention objectives.
Develop and launch learning pilot to enhance business acumen resulting in four commercial opportunities. |
All threshold, target and stretch measures have been achieved. | |||
People Result: Stretch |
Payout: 30% |
(1) | The financial figures for Tampa Electric are shown in USD. |
(2) | Percentage payouts, below or above target for financial measures, are interpolated on a scale between each level of performance (50 per cent for threshold, 100 per cent for target and capped at 200 per cent for stretch). |
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Customer (15% weighting)
Asset Management (15% weighting)
Measures Included: | Highlights | |||
1% increase in the solar net capacity factor vs forecasted solar net capacity factor for 2023.
Update the consolidated five-year Technology Roadmap including business objectives, value created and project milestones.
Cybersecurity training completion rate of ≥95%.
Develop operational plan to mitigate fuel expense and implement at least two initiatives. |
All threshold and target measures were achieved. | |||
Asset Management Result: Target |
Payout: 15% |
Total 2023 Tampa Electric Scorecard Result: 108.5% |
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Notice of Annual Meeting of Common Shareholders and Management Information Circular
Long-term Incentive Program
In 2023, there were three primary components of long-term incentive compensation for senior management, including the NEOs: the Performance Share Unit Plan (the PSU Plan), the Restricted Share Unit Plan (the RSUs Plan) and the Senior Management Stock Option Plan (the Stock Option Plan). The MRCC is responsible for granting PSUs, RSUs and stock options.
The number of PSUs, RSUs and stock options granted to senior management is determined after considering competitive benchmarking data and the individuals level of responsibility within the Company. Grants are calculated each year based on each executives long-term incentive target percentage and base salary and, generally, the grant amount increases with the level of responsibility. The values of PSUs, RSUs and stock options increase or decrease over the term of a particular grant based on increases or decreases in Emeras common share price.
The MRCC considers previous grants and looks at a history of total compensation each year before approving any new PSU, RSU or stock option grants for senior management (including the NEOs). This helps to ensure grants remain reasonable in light of market data, the performance of the Company and the performance of the individual.
In 2023, PSUs made up 50 per cent of the target long-term incentive compensatory value for each of Emeras most senior executive officers, with the remaining 50 per cent divided equally between RSUs and stock options. This mix is aligned with market practice and provides for a balance between company performance and retention, while maintaining the Companys pay-for-performance strategy by closely linking a significant portion of the executives compensation to that of the shareholder experience.
The table below provides a summary of the 2023 long-term incentive grants awarded to the NEOs.
Options granted (#) |
Options grant value ($) (1) |
PSUs granted (#) |
PSUs grant value ($) (2) |
RSUs granted (#) |
RSUs grant value ($) (2) |
Total LTIP value ($) |
||||||||||||||||||||||
Scott Balfour |
206,900 | 1,458,645 | 56,475 | 2,917,499 | 28,239 | 1,458,827 | 5,834,971 | |||||||||||||||||||||
Greg Blunden |
48,400 | 341,220 | 13,202 | 682,015 | 6,596 | 340,749 | 1,363,984 | |||||||||||||||||||||
Archibald Collins |
31,900 | 224,895 | 8,711 | 450,010 | 4,357 | 225,083 | 899,988 | |||||||||||||||||||||
Karen Hutt |
34,100 | 240,405 | 9,321 | 481,523 | 4,667 | 241,097 | 963,025 | |||||||||||||||||||||
Bruce Marchand |
30,900 | 217,845 | 8,440 | 436,010 | 4,223 | 218,160 | 872,015 |
(1) | Stock options are granted based on the Black-Scholes methodology. Please see the Senior Management Stock Option Plan section on page 89 for details on the Black-Scholes results and the Companys use of a floor value ratio. |
(2) | PSU and RSU grant values were calculated using the 50-day average closing share price of an Emera common share for the last 50 trading days of 2022, which was $51.66. |
More details about the PSU Plan, the RSU Plan and the Stock Option Plan are set forth below.
Performance Share Unit Plan
The PSU Plan is designed to retain and incentivize employee participants by allowing senior management and key employees in specific roles to participate in the long-term success of the Company. A PSU is a notional share unit that is based on the value of an Emera common share the value of a PSU changes directly in correlation to the value of an Emera share. PSUs also earn dividends like Emera shares; when a dividend is paid on Emeras 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 Emeras financial performance over the three-year vesting period, the plan aligns the interests of senior leaders with the interests of Emeras 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.
EMERA INCORPORATED | 85 |
Notice of Annual Meeting of Common Shareholders and Management Information Circular
At the end of the performance period, a performance factor is applied to the PSU grant based on the achievement of the financial objectives. If the Company fails to meet the performance objectives for a particular PSU grant, the Plan may pay out at less than target, or may not pay out any amounts at all. Even if targets are exceeded, the maximum performance factor is 200 per cent.
Accordingly, the amount payable to participants, including NEOs, at the end of the three-year performance period is determined by:
Like the methodology on the grant, the payout is based on the average 50-trading-day closing price for Emera common shares at the end of the three-year performance period to smooth out short-term price fluctuations. Payments are made in cash.
2023 PSU Grant Performance Metrics
The Companys long-term focus continues to be on EPS growth and long-term shareholder value creation. Accordingly, the Company used the following two weighted metrics for the 2023 PSU grant:
1. | Compensation EPS (1) growth, which continues to be a fundamental measure of the increase in profitability of the Company; and |
2. | Relative TSR, a key measure of Emeras relative performance against a Canadian custom peer group. |
The TSR metric was introduced with the 2022 PSU grant and will measure Emeras TSR against the average of the below Canadian custom peer group, which is comprised of close industry peers who Emera competes with for capital.
Relative Total Shareholder Return Canadian Custom Peer Group
Company name |
Industry classification | |
Fortis Inc. Hydro One Limited Algonquin Power & Utilities Corp. Canadian Utilities Limited AltaGas Ltd. Enbridge Inc. TC Energy Corporation |
Electric Utilities Electric Utilities Multi-Utilities Multi-Utilities Gas Utilities Oil, Gas and Consumable Fuels Oil, Gas and Consumable Fuels |
The combination of the two metrics effectively measures managements contributions to the creation of long-term value for shareholders.
The performance period for PSUs granted in 2023 is from January 1, 2023 to December 31, 2025 and the table below shows the performance factor levels:
Metric |
Weighting | Threshold (50%) | Target (100%) | Stretch (200%) | ||||||||||||
Average annual growth in Compensation EPS |
75% | 3% | 6% | 9% | ||||||||||||
Relative Total Shareholder Return |
25% | |
Equal to -25% (i.e., 2,500 bps) of Peer Group Average |
|
|
Equal to Peer Group Average |
|
|
Greater than or equal to +25% (i.e., 2,500 bps) of Peer Group Average |
|
The threshold, target and stretch levels of performance are consistent with those for previous grants, and are calibrated against a combination of the Companys five-year business plan projections, dividend growth rate, actual and forecasted performance levels of peers, and overall assessment of the expectations of shareholders.
(1) | Adjusted EPS for compensation purposes (Compensation EPS) is a non-GAAP financial measure that does not have a standardized meaning under USGAAP. Calculation of this measure and reconciliation to the nearest GAAP measure is discussed on page 88. |
86 | EMERA INCORPORATED |
Notice of Annual Meeting of Common Shareholders and Management Information Circular
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 Emeras control, which could cause actual results to differ materially from the performance targets. Please see the cautionary statement in Emeras 2023 Annual Report with respect to risks and assumptions relevant to Emeras determination of performance targets for compensation purposes.
Performance Share Unit Plan Results
The 2021 PSU grant had a performance period of January 1, 2021 to December 31, 2023 and was subject to two performance metrics:
1. | Compensation EPS growth weighted at 75 per cent, which is a fundamental measure of the increase in profitability of the Company; and |
2. | Compensation cash flow, pre-working capital weighted at 25 per cent, which measures the Companys success in focusing on cash generation and is a key driver of long-term value for shareholders. |
In addition to the above metrics, the 2021 PSU grant was subject to a TSR modifier, which could increase or decrease the performance factor resulting from the two performance metrics by 25 per cent based on Emeras TSR compared to the TSR of the S&P/TSX Capped Utilities Index over the three-year performance period. If Emeras TSR was positioned in the top quartile of performance of companies in the S&P/TSX Capped Utilities Index, the performance factor would be increased by 25 per cent; if Emeras TSR was positioned in the bottom quartile, the performance factor would be reduced by 25 per cent. There is no adjustment if Emeras TSR is in the second or third quartile of performance. This allowed the Company to focus on its specific business objectives, but still manage shareholder expectations by adjusting the results for relative performance.
The performance factor could range from 0 per cent to 200 per cent. The maximum performance factor is 200 per cent, even with the impact of the TSR modifier. If the performance metric results multiplied by the TSR modifier exceed 200 per cent, the performance factor would be capped at 200 per cent. In addition, if Emeras TSR is negative on an absolute basis, then the TSR 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 Emeras TSR is higher while still being negative. This provision helps ensure payouts are reasonable when shareholders experience low returns on their investment.
The threshold, target and stretch levels and results are shown in the table below:
2021 PSU grant metric |
Weighting | Threshold (50%) | Target (100%) | Stretch (200%) | ||||||||||||
Compensation EPS (1): three-year compound annual growth rate |
75 | % | 2 | % | 6 | % | 10 | % | ||||||||
Compensation cash flow, pre-working capital (1): three-year compound annual growth rate |
25 | % | 2 | % | 6 | % | 10 | % |
The results were as follows:
2021 PSU grant metric |
2020 | 2023 | Three-year compound annual growth rate |
Weighted performance result |
||||||||||||
Compensation EPS |
$ | 2.68 | $ | 2.96 | 3.3 | % | 50 | % | ||||||||
Compensation cash flow, pre-working capital |
$ | 1,420M | $ | 1,900M | 10.2 | % | 50 | % | ||||||||
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|
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Performance factor |
|
100 | % | |||||||||||||
|
|
(1) | Compensation EPS and Compensation cash flow, pre-working capital, are non-GAAP financial measures that do not have standardized meaning under USGAAP. A reconciliation to the nearest GAAP measure is discussed further on page 88. |
EMERA INCORPORATED | 87 |
Notice of Annual Meeting of Common Shareholders and Management Information Circular
The compensation EPS and compensation cash flow, pre-working capital figures shown in the preceding table are adjusted from the Companys reported figures as reconciled below. Like the approach used for determining the corporate scorecard results, and similar to previous PSU grant results, the Company has removed the cash flow effect of the over/under recovery of fuel and storm costs at both Tampa Electric and Nova Scotia Power.
Adjusted EPS (Basic) Reconciliation ($) |
2020 | 2023 | ||||||
Adjusted EPS (basic) (1) |
2.68 | 2.96 | ||||||
No changes made to Adjusted EPS (basic) |
| | ||||||
|
|
|
|
|||||
Compensation EPS |
2.68 | 2.96 | ||||||
|
|
|
|
Compensation cash flow, pre-working capital reconciliation ($) |
2020 | 2023 | ||||||
Reported operating cash flow |
1,637 | 2,241 | ||||||
Less: Working capital |
(217 | ) | 95 | |||||
Less: Fuel over-recovery at TECO |
| (587 | ) | |||||
Add: Fuel under-recovery at NSP |
| 222 | ||||||
Add: Storm under-recovery at NSP |
| 21 | ||||||
Less: Storm over-recovery at TECO |
| (92 | ) | |||||
|
|
|
|
|||||
Compensation cash flow, pre-working capital |
1,420 | 1,900 | ||||||
|
|
|
|
(1) | Adjusted EPS (basic) is a non-GAAP financial ratio that does not have standardized meanings under USGAAP. A reconciliation of adjusted net income to reported net income and the resulting calculation of adjusted EPS (basic) for 2020 and 2023 are included in the Non-GAAP Financial Measures section of Emeras Managements Discussion and Analysis as at February 16, 2021 and the Non-GAAP Financial Measures and Ratios section of Emeras Managements Discussion and Analysis as at February 26, 2024, respectively. These sections are incorporated by reference herein and as filed on the company website at www.emera.com and on SEDAR+ at www.sedarplus.com. |
The Committee applied the principles laid out in the 2023 Emera Corporate Scorecard in determining the adjustments to the reported figures.
The resulting overall performance factor applied to the 2021 PSU grant was 100 per cent (or 1.0), based on Emeras compensation EPS growth rate below target performance and the growth in compensation cash flow, pre-working capital exceeding stretch performance. Since Emeras TSR was in the third quartile of performance of the companies in the S&P/TSX Capped Utilities Index for 2021 to 2023, the relative TSR modifier was not triggered.
The total payout for all PSU Plan participants in respect of the 2021 PSU grant was approximately $13.3 million. The payout for each participant was 101.6 per cent of the original grant value, which factors in share price, notional dividend reinvestment and the performance factor.
88 | EMERA INCORPORATED |
Notice of Annual Meeting of Common Shareholders and Management Information Circular
Restricted Share Unit Plan
The RSU Plan is designed to achieve more balance between risk and leverage in Emeras long-term incentive programs, while remaining consistent with our pay-for-performance philosophy.
An RSU is a notional share unit that is based on the value of an Emera common share the value of an RSU changes directly in correlation to the value of an Emera share. RSUs also earn dividends similar to Emera shares; when a dividend is paid on Emeras common shares, each participant is allocated additional RSUs based on the dividend paid on an equivalent number of Emera common shares.
Similar to PSUs, designated senior leaders or key employees are awarded RSUs annually based on a pre-determined target of their base salary and the average 50-trading-day Emera common share price immediately preceding the effective grant date (the average is used to smooth out any short-term fluctuations in the share price). Each RSU grant has a three-year vesting period.
At the end of the three-year period, RSUs are valued and paid out in cash calculated by multiplying the original number of RSUs granted and all additional notional dividends by the average 50-trading-day closing price for Emera common shares at the end of the three-year period. The calculation is as follows:
RSU Plan Results
The 2021 RSU grant had a vesting period of January 1, 2021 to December 31, 2023.
The total payout for all RSU Plan participants in respect of the 2021 RSU grant was approximately $9.9 million. The payout for each participant was 101.6 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 and notional dividend reinvestment.
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 managements recommendation, which employees of the Company and its operating companies 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 executives 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 2023 as part of their long-term incentive.
The Company has historically valued stock options based on the Black-Scholes valuation methodology. However, the Committee adopted a floor value ratio of 10 per cent in 2015, following a review of market practices on valuation methodologies. If the Black- Scholes methodology leads to a value ratio that is less than 10 per cent, the floor of 10 per cent will apply. All other factors being equal, the use of a higher value ratio leads to fewer options. The 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 Program, while reflecting prevailing market conditions. The exercise price for stock options is the closing price of an Emera common share on the day immediately preceding the effective grant date. Options have a 10-year term and must be exercised before the expiry date and any unexercised options are forfeited upon expiry.
For the 2023 stock option grant, the Black-Scholes valuation resulted in a value ratio ranging from 8.4 per cent to 12.9 per cent. The range was dependent on the number of months over which the volatility calculation was measured, from 12 to 120 months. Because the valuation was 12.9 per cent over a 36-month period, the floor value ratio was not applied. Accordingly, the value of each option granted in 2023 was $7.05, which was 12.9 per cent of the closing Emera common share price of $54.64 on February 24, 2023, the trading day immediately preceding the grant date. The share price of $54.64 is also the exercise price for the 2023 grant.
EMERA INCORPORATED | 89 |
Notice of Annual Meeting of Common Shareholders and Management Information Circular
Commencing with the 2022 stock option grant, stock options vest in 20 per cent increments on the first, second, third, fourth and fifth anniversaries of the grant date. Unless a stock option has expired, vested options may be exercised by the earlier of either six months following the date of termination without cause or the expiry of the option in accordance with its terms and by the earlier of either 60 days following the date of termination for cause or resignation or the expiry of the option in accordance with its terms. If stock options are not exercised within such time, they expire. In the event of death, any unvested options that would vest within 12 months of the date of death will vest immediately and all vested options may be exercised by the option holders beneficiary or legal representative by the earlier of either six months from the date of death or the expiry date of the option. Any unvested options that are not scheduled to vest within 12 months of the option holders death will expire. Senior executives are entitled to an early retirement provision, as defined in the Stock Option Plan, which allows vested options that are held at the time of retirement to remain exercisable until the end of the options term. In the case of early retirement, unvested options held as of the retirement date will expire. The Stock Option Plan also provides for a normal retirement provision, which allows unvested stock options to continue to vest in full and in normal course and be exercised until the end of the options term. In both retirement scenarios and in consideration of the continued vesting, the executive must agree and adhere to non-compete and non-solicit restrictive covenants for a period of: (1) 24 months in the case of the CEO and (2) 18 months in the case of all other option holders (or a shorter period if the MRCC considers it appropriate) from the retirement date. If the option holder fails to comply with any of the restrictive covenants, then all unvested and vested options will expire as of the date of such a breach. If a change of control occurs and an executive is terminated within 24 months of the change of control and for good reason as defined in the plan text and in this Circular under Termination and Change of Control Benefits, unvested options held at the time of termination vest immediately and must be exercised by the earlier of either six months from the termination date or the expiry date of the option. Continued compliance with any obligations under the executives terms of employment, including non-compete and non-solicit covenants in favour of the Company is required. In the event of a change of control, the Board may, without the consent of the option holder: (1) convert or exchange any outstanding options for rights or other securities of substantially equal value in any entity participating in or resulting from the change of control, (2) accelerate the vesting of options or terminate options upon or immediately prior to the change of control, (3) substitute shares of the entity resulting from the change of control for shares of the Company, or (4) terminate options in exchange for an amount of cash and/or property equal to the shares underlying the options, less the exercise price, as of the date of the change of control. If the Board determines in good faith that the options would have no value upon exercise, the Board may terminate the options without payment. Please see Termination and Change of Control Benefits for the NEOs entitlements on departure.
The maximum percentage of shares under all security-based compensation arrangements (including the Stock Option Plan and the Employee Common Share Purchase Plan) issuable to insiders of the Company at any time is 10 per cent of the issued and outstanding shares of the Company. The maximum number of shares to be optioned to any one person under the Stock Option Plan is 5 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 14.7 million shares, or approximately 5.17 per cent of the total issued and outstanding common shares of the Company as of December 31, 2023.
There have been 8,851,186 common shares issued under the Stock Option Plan since its inception, which represents approximately 3.12 per cent of the total issued and outstanding common shares of the Company as of December 31, 2023, leaving 5,848,814 common shares reserved for issuance under the Plan, representing 2.06 per cent of the total issued and outstanding common shares as at December 31, 2023. There are 3,095,604 common shares issuable under actual grants of options, which represent approximately 1.09 per cent of the total issued and outstanding common shares of the Company as of December 31, 2023 and, of that amount, 1,842,349 are vested and 1,253,255 are unvested.
90 | EMERA INCORPORATED |
Notice of Annual Meeting of Common Shareholders and Management Information Circular
The Board of Directors of the Company may amend or discontinue the Stock Option Plan by resolution at any time and may, without shareholder approval, make amendments such as changes to vesting provisions and other minor changes of a housekeeping nature; however, shareholder approval is required for any amendment that:
| Increases the number of common shares reserved for issuance, except an increase made in proportion to an increase in the number of common shares outstanding due to a stock dividend, stock split, amalgamation, reorganization, merger or similar event; |
| Extends eligibility to participate to non-employee Directors; |
| Permits rights under the Stock Option Plan to be transferred other than for normal estate settlement purposes; |
| Permits awards to be granted under the Stock Option Plan in addition to options; |
| Increases either of the 10 per cent insider participation limits; |
| Reduces the option price of an option except for the purpose of maintaining option value in connection with a change of control or pursuant to the provisions in the Stock Option Plan, which permit equitable adjustments to be made to the option price in connection with a stock dividend, stock split, share reclassification, amalgamation, reorganization, merger or similar event; |
| Permits the expiry of a stock option to be beyond 10 years from its date of grant (except in the case of the automatic extension of the expiry date of an option as a result of the expiry date falling within a blackout period or within five business days of the blackout period being lifted); or |
| Deletes or reduces the range of amendments that require shareholder approval under this paragraph. |
The table below summarizes certain ratios regarding the Stock Option Plan, namely dilution, burn rate and overhang as defined in the table.
2023 (%) | 2022 (%) | 2021 (%) | ||||||||||
Dilution |
||||||||||||
(number of options outstanding, divided by the weighted average total issued and outstanding common shares for the applicable fiscal year) |
1.13 | 1.08 | 1.01 | |||||||||
Burn rate |
||||||||||||
(number of options granted in an applicable fiscal year, divided by the weighted average total issued and outstanding common shares for the applicable fiscal year) |
0.18 | 0.18 | 0.25 | |||||||||
Overhang |
||||||||||||
(shares available for issuance, plus options outstanding, divided by the weighted average total issued and outstanding common shares for the applicable fiscal year) |
2.14 | 2.26 | 2.41 |
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.
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 an annual perquisite allowance, which is paid in equal bi-weekly cash instalments over the course of the year and is reviewed on an annual basis. In 2023, Mr. Balfour received an annual perquisite allowance of $30,000 and the other NEOs received an annual perquisite allowance of $20,000. The annual perquisite allowance is designed to cover additional benefits, such as:
| Monthly car allowance plus mileage, as applicable; and |
| Annual wellness/fitness allowance. |
These benefits, including company paid parking, are considered taxable benefits and are reported in the Summary Compensation Table for the NEOs.
EMERA INCORPORATED | 91 |
Notice of Annual Meeting of Common Shareholders and Management Information Circular
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. Beginning in 2023, RSUs no longer contribute to ownership levels. In consideration of this change, impacted executives will have an additional two years to obtain their ownership requirement.
All NEOs are also subject to a one-year post-retirement hold period, which requires the NEOs to maintain a material financial stake in the Company after retirement by holding at least the minimum ownership level of Emera shares for one year after they retire from the Company. This helps maintain a focus on long-term sustainable value and prevents executives from timing their departure to maximize the cash-out value of their equity stake in the Company.
Share ownership is calculated based on: (1) the number of Emera shares an executive owns; and (2) the number of DSUs acquired pursuant to the DSU Plan, which are considered share equivalents.
PSUs, RSUs 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 executives 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 Companys anti-hedging policy, which prohibits them from hedging, pledging, monetizing, or otherwise reducing or limiting their economic risk with respect to any Emera securities they hold, directly or indirectly, including DSUs, RSUs, PSUs, and stock options. These prohibited transactions include short- selling, options, puts and calls, as well as derivatives such as forward contracts, equity swaps, collars and futures, or entering into limited recourse loans secured by securities of Emera.
The share ownership levels for the NEOs are set out below. The values shown are based on the closing price of Emeras common shares on December 29, 2023 of $50.30 (units have been rounded). The table does not include the DSUs that will be allocated as part of the 2023 short-term incentive payout, as described in 2023 DSU Plan Allocations.
Name |
Required ownership level as a multiple of base salary |
Required ownership level ($) |
DSUs held (#) |
Value of DSUs held ($) |
Common shares held (#) |
Value of common shares held ($) |
Total share and share equivalent ownership ($) |
Multiple of base salary (1) |
Status of share ownership requirements |
Outstanding RSU ($) |
Total Value of DSUs, Common Shares and Outstanding RSUs ($) |
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Scott Balfour |
5 | 5,665,000 | 139,809 | 7,032,411 | 76,190 | 3,832,345 | 10,864,756 | 9.6 | Met | 2,812,317 | 13,677,079 | |||||||||||||||||||||||||||||||||
Greg Blunden |
3 | 1,860,000 | 63,250 | 3,181,488 | 2,998 | 150,791 | 3,332,279 | 5.4 | Met | 656,357 | 3,988,644 | |||||||||||||||||||||||||||||||||
Archibald Collins |
3 | 1,800,000 | 6,206 | 312,141 | 11,732 | 590,107 | 902,247 | 1.5 | On Track | 405,030 | 1,307,263 | |||||||||||||||||||||||||||||||||
Karen Hutt |
3 | 1,605,000 | 20,561 | 1,034,226 | 2,695 | 135,565 | 1,169,791 | 2.2 | On Track | 460,713 | 1,630,489 | |||||||||||||||||||||||||||||||||
Bruce Marchand |
3 | 1,635,000 | 38,713 | 1,947,256 | 3,815 | 191,908 | 2,139,164 | 3.9 | Met | 426,071 | 2,565,255 |
(1) | Based on executives respective base salary as of December 31, 2023. |
Three of the five NEOs have met their required ownership levels. Considering the changes to the share ownership calculations to exclude RSUs, Mr. Collins and Ms. Hutt have been granted a two-year extension to reach their ownership requirement.
92 | EMERA INCORPORATED |
Notice of Annual Meeting of Common Shareholders and Management Information Circular
While RSUs no longer contribute to required ownership levels, the Committee recognizes that they do continue to provide a significant linkage between senior management and shareholder interests. As such, we have included the value of unvested RSU holdings for the NEOs as of December 31, 2023 in the preceding table. The total value of outstanding DSUs, common shares and outstanding RSUs shown is based on the closing share price of Emeras common shares on December 29, 2023 of $50.30 (units have been rounded).
3.4 | Performance Graph |
The following performance graph compares Emeras cumulative 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. It also compares TSR to the trend in the companys total direct compensation (TDC) paid to executive officers as reported in the Summary Compensation Table during the same period.
Cumulative Total Return on $100 Investment December 31, 2018 to December 31, 2023
As at December 31 |
2018 ($) | 2019 ($) | 2020 ($) | 2021 ($) | 2022 ($) | 2023 ($) | ||||||||||||||||||||
|
Emera Inc. |
100.00 | 133.66 | 135.47 | 165.70 | 142.02 | 145.60 | |||||||||||||||||||
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S&P/TSX Capped Utilities Total Return |
100.00 | 137.49 | 158.50 | 176.96 | 158.27 | 158.56 | |||||||||||||||||||
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S&P/TSX Composite Total Return |
100.00 | 122.88 | 129.76 | 162.32 | 152.83 | 170.79 | |||||||||||||||||||
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TDC ($ thousands) |
13,136 | 13,540 | 15,608 | 15,263 | 15,360 | 16,639 |
Emeras cumulative TSR for the five-year period from December 31, 2018 to December 31, 2023 was 46 per cent, compared to the 59 per cent return of the S&P/TSX Capped Utilities Index and 71 per cent return of the S&P/TSX Composite Index. Emeras TSR increased 3 per cent over the one-year period from 2022 to 2023 and 7 per cent over the three-year period, exceeding the less than one per cent increase realized by the S&P/TSX Capped Utilities Index over the same time periods. The above graph also shows total compensation for our NEOs over the past six years, which includes annual base salary, long-term incentive grant value, and annual short-term incentive payouts, demonstrating alignment between our TSR and NEO compensation. NEO TDC increased from 2018 to 2020 in alignment with TSR, leveled off in 2021 and 2022, which aligned with a decrease in TSR in 2022, and increased again in 2023 along with TSR.
EMERA INCORPORATED | 93 |
Notice of Annual Meeting of Common Shareholders and Management Information Circular
TOTAL SHAREHOLDER RETURN AND PRESIDENT AND CEO COMPENSATION
As noted in the Message from the Management Resources and Compensation Committee to Our Shareholders, a fundamental principle of Emeras 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.
Considering this principle, at the end of 2023 the Company undertook its annual analysis of the alignment between the President and CEOs compensation and the experience of shareholders. The analysis reviewed the compensation of the President and CEO over the past five 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 five different measurement periods, recognizing that shareholders have acquired their shares at different times. Each period had the same end point (December 31, 2023) but started at a different beginning period, from January 1, 2019 to January 1, 2023. The analysis measured the dollar return per $100 of investment over each period as compared to the President and CEOs economic experience, measured by the dollars realized and realizable per $100 of target compensation awarded over the same periods.
The following lookback table shows the results of the review:
Pay year |
Target total direct compensation ($) (1) (2) |
Total realized/ realizable value at Dec. 31, 2023 ($) (3) |
Measurement period |
Realized/ realizable value of $100 target pay awarded to CEO ($) (3) |
Value of $100 shareholder investment as of Dec. 31, 2023 ($) (4) |
Difference ($) | ||||||||||||||||
2019 |
5,900 | 6,686 | Jan. 1, 2019 Dec. 31, 2023 | 113 | 146 | 33 | ||||||||||||||||
2020 |
7,000 | 7,611 | Jan. 1, 2020 Dec. 31, 2023 | 109 | 109 | 0 | ||||||||||||||||
2021 |
7,700 | 6,727 | Jan. 1, 2021 Dec. 31, 2023 | 87 | 107 | 20 | ||||||||||||||||
2022 |
7,865 | 6,146 | Jan. 1, 2022 Dec. 31, 2023 | 78 | 88 | 10 | ||||||||||||||||
2023 |
8,101 | 6,933 | Jan. 1, 2023 Dec. 31, 2023 | 86 | 103 | 17 | ||||||||||||||||
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Average | 95 | 111 | 16 | |||||||||||||||||||
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(1) | The lookback table shows the compensation of the President and CEO, Scott Balfour, for 2019 through 2023. |
(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, 2023. |
(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 Emeras compensation framework provided appropriate alignment between the President and CEOs compensation and the shareholder experience over the long term. This analysis also assists the MRCC in considering various compensation outcomes when assessing compensation changes for the President and CEO each year.
In keeping with Emeras compensation philosophy, a significant component of NEO compensation consists of long-term incentives (PSUs, RSUs and stock options), which are designed to focus executives on the long-term success of the Company. These long- term incentives are directly affected by changes in Emeras common share price and TSR. This helps create a direct correlation between the shareholder experience and the compensation the Company pays its senior executives.
As described in Performance Share Unit Plan, each PSU grant is subject to the achievement of financial objectives and, at the end of the performance period, a performance factor is applied, which is determined based on the extent to which the Company has met those objectives. The performance factors for the PSU Plan, expressed in terms of a percentage, for the past five years were 100 per cent for the period ended in 2019, 112 per cent for the period ended in 2020, 74 per cent for the period ended in 2021, 140 per cent for the period ended in 2022 and 100 per cent for the period ended in 2023.
The total annual salary, short-term and long-term incentive payouts in 2023 for the five NEOs totalled $13.6 million, which represents 1.39 per cent of the Companys net earnings attributable to common shareholders of $978 million. The MRCC is comfortable that the payout totals for 2023 are reasonable based on the Companys performance and demonstrate that the Companys compensation programs are aligned with the interests of our shareholders.
94 | EMERA INCORPORATED |
Notice of Annual Meeting of Common Shareholders and Management Information Circular
3.5 | NEO Summary Compensation Table |
The table below shows the compensation awarded to the Companys NEOs for the last three fiscal years.
Non-equity incentive plan compensation |
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Name and principal position |
Year | Salary ($) (1) | Share-based awards ($) (2) |
Option- based awards ($) (3) |
Annual incentive plans ($) (4) |
Pension value ($) |
All other compensation ($) (5) |
Total compensation ($) |
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Scott Balfour |
2023 | 1,132,238 | 4,376,325 | 1,458,645 | 1,308,615 | 261,305 | 35,656 | 8,572,784 | ||||||||||||||||||||||||
President and Chief Executive |
2022 | 1,100,000 | 4,248,511 | 1,416,492 | 1,085,700 | 361,651 | 35,656 | 8,248,010 | ||||||||||||||||||||||||
Officer |
2021 | 1,098,077 | 4,124,917 | 1,375,101 | 1,288,100 | 357,000 | 37,349 | 8,280,544 | ||||||||||||||||||||||||
Greg Blunden |
2023 | 619,538 | 1,022,765 | 341,220 | 572,880 | 97,795 | 25,656 | 2,679,854 | ||||||||||||||||||||||||
Chief Financial Officer |
2022 | 599,654 | 990,150 | 329,868 | 473,760 | 105,847 | 25,656 | 2,524,935 | ||||||||||||||||||||||||
2021 | 584,519 | 965,077 | 321,930 | 548,028 | 88,000 | 27,749 | 2,535,303 | |||||||||||||||||||||||||
Archibald Collins |
2023 | 598,500 | 675,093 | 224,895 | 520,944 | 356,511 | 333,589 | 2,709,532 | ||||||||||||||||||||||||
President and Chief Executive |
2022 | 534,192 | 561,898 | 187,110 | 602,838 | 341,502 | 274,413 | 2,501,953 | ||||||||||||||||||||||||
Officer, Tampa Electric Company |
2021 | 490,374 | 468,655 | 156,366 | 377,996 | 522,662 | 255,383 | 2,271,435 | ||||||||||||||||||||||||
Karen Hutt |
2023 | 534,423 | 722,620 | 240,405 | 432,548 | 55,611 | 22,376 | 2,007,983 | ||||||||||||||||||||||||
EVP, Business Development |
2022 | 508,846 | 688,610 | 229,383 | 352,359 | 52,748 | 22,376 | 1,854,322 | ||||||||||||||||||||||||
& Strategy |
2021 | 459,327 | 552,066 | 183,960 | 377,062 | 49,000 | 24,469 | 1,645,884 | ||||||||||||||||||||||||
Bruce Marchand |
2023 | 545,000 | 654,171 | 217,845 | 440,633 | 96,600 | 21,656 | 1,975,905 | ||||||||||||||||||||||||
Chief Risk and |
2022 | 544,769 | 653,704 | 218,295 | 376,541 | 150,062 | 21,656 | 1,965,027 | ||||||||||||||||||||||||
Sustainability Officer |
2021 | 534,519 | 641,872 | 214,109 | 438,540 | 171,000 | 23,749 | 2,023,789 |
(1) | The figure shown represents the actual base earnings paid each year. |
(2) | The figure shown is the value of PSU and RSU grants as of the effective grant date. The grant value of PSUs and RSUs granted in 2023 was based on the average 50-trading-day closing share price up to December 31, 2022 ($51.66). The 50-day share price average is used for PSU and RSU grants to smooth out any short-term fluctuations in share price immediately preceding the grant date. The value of PSUs on payout is subject to the achievement of specific performance objectives over the respective three-year performance period. If those objectives are not met, payouts may be less than the initial value of the grant noted in this column, and if performance objectives are exceeded, payouts may be higher than the amount noted in this column. |
(3) | The value of each stock option granted to the NEOs in 2023 was determined to be equal to 12.9 per cent of the February 24, 2023 closing share price of $54.64 or $7.05 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 2023 resulted in a value ratio of 12.9 per cent to 8.4 per cent, using an estimated dividend yield of 5.3 per cent, and a risk-free interest rate of 3.29 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 23.3 per cent to 17.2 per cent. Because the Black- Scholes valuation was above 10 per cent when calculated over a 36-month period, the actual result was used. |
(4) | In 2023, all NEOs, except Mr. Collins, participated in the Emera Corporate Scorecard, which had a result of 115.5 per cent. Mr. Collins participated in the Tampa Electric Company scorecard, which had a result of 108.53 per cent. The Short-term Incentive Plans and the 2023 results are described in greater detail in Short-term Incentive Plan. The figures shown reflect amounts earned in the 2023 performance year and paid in 2024. Mr. Balfour and Mr. Blunden elected to receive 50 per cent of their payout in the form of DSUs. |
(5) | All other compensation in 2023 consists of: for Mr. Balfour, a cash perquisite allowance of $30,000 and other taxable benefits; for Mr. Blunden, a cash perquisite allowance of $20,000 and other taxable benefits; for Ms. Hutt, a cash perquisite allowance of $20,000 and other taxable benefits; and for Mr. Marchand, a cash perquisite allowance of $20,000 and other taxable benefits. Mr. Collins was required to relocate from Nova Scotia to Tampa, Florida as President and CEO of Tampa Electric. Mr. Collins amount consists of a cash perquisite allowance of $20,000, a housing allowance of $185,298, a cost- of-living allowance of $80,812, and family travel allowance of $43,478. The assignment-related allowances are tax protected under the Companys Tax Equalization Policy. |
EMERA INCORPORATED | 95 |
Notice of Annual Meeting of Common Shareholders and Management Information Circular
Outstanding Share-based Awards and Option-based Awards
The following table describes all option-based and share-based awards outstanding as of December 31, 2023 for each NEO:
Option-based awards (1) (stock options) |
Share-based awards (PSUs, RSUs and DSUs) |
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Name |
Number of securities underlying unexercised option (#) |
Option exercise price ($) |
Option expiration date |
Value of unexercised in-the- money options ($) (2) |
Number of shares or units of shares that have not vested (#) (3) |
Market or payout value of share- based awards that have not vested ($) (4) |
Market or payout value of vested share-based awards that have not been paid out ($) (5) |
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Scott Balfour |
34,800 | 32.35 | 2/11/2024 | 624,660 | 167,738 | 8,066,533 | 6,723,432 | |||||||||||||||||||||
40,400 | 42.71 | 2/11/2025 | 306,636 | |||||||||||||||||||||||||
52,100 | 46.19 | 2/17/2026 | 214,131 | |||||||||||||||||||||||||
66,300 | 45.16 | 2/14/2027 | 340,782 | |||||||||||||||||||||||||
175,400 | 39.93 | 2/13/2028 | 1,818,898 | |||||||||||||||||||||||||
210,100 | 46.39 | 2/20/2029 | 821,491 | |||||||||||||||||||||||||
208,300 | 60.03 | 2/19/2030 | | |||||||||||||||||||||||||
269,100 | 51.12 | 2/17/2031 | | |||||||||||||||||||||||||
204,400 | 58.26 | 2/15/2032 | | |||||||||||||||||||||||||
206,900 | 54.64 | 2/26/2033 | | |||||||||||||||||||||||||
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Greg Blunden |
9,325 | 45.16 | 2/14/2027 | 47,931 | 39,150 | 1,882,744 | 3,041,705 | |||||||||||||||||||||
23,500 | 39.93 | 2/13/2028 | 243,695 | |||||||||||||||||||||||||
36,675 | 46.39 | 2/20/2029 | 143,399 | |||||||||||||||||||||||||
42,000 | 60.03 | 2/19/2030 | | |||||||||||||||||||||||||
63,000 | 51.12 | 2/17/2031 | | |||||||||||||||||||||||||
47,600 | 58.26 | 2/15/2032 | | |||||||||||||||||||||||||
48,400 | 54.64 | 2/26/2033 | | |||||||||||||||||||||||||
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Archibald Collins |
30,600 | 51.12 | 2/17/2031 | | 24,149 | 1,161,340 | 298,426 | |||||||||||||||||||||
27,000 | 58.26 | 2/15/2032 | | |||||||||||||||||||||||||
31,900 | 54.64 | 2/26/2033 | | |||||||||||||||||||||||||
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Karen Hutt |
8,500 | 46.19 | 2/17/2026 | 34,935 | 27,459 | 1,320,489 | 988,786 | |||||||||||||||||||||
11,900 | 45.16 | 2/14/2027 | 61,166 | |||||||||||||||||||||||||
13,875 | 39.93 | 2/13/2028 | 143,884 | |||||||||||||||||||||||||
19,400 | 46.39 | 2/20/2029 | 75,854 | |||||||||||||||||||||||||
20,400 | 60.03 | 2/19/2030 | | |||||||||||||||||||||||||
36,000 | 51.12 | 2/17/2031 | | |||||||||||||||||||||||||
33,100 | 58.26 | 2/15/2032 | | |||||||||||||||||||||||||
34,100 | 54.64 | 2/26/2033 | | |||||||||||||||||||||||||
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Bruce Marchand |
9,090 | 42.71 | 2/11/2025 | 68,993 | 25,418 | 1,222,332 | 1,861,700 | |||||||||||||||||||||
19,500 | 46.19 | 2/17/2026 | 80,145 | |||||||||||||||||||||||||
32,500 | 45.16 | 2/14/2027 | 167,050 | |||||||||||||||||||||||||
30,675 | 39.93 | 2/13/2028 | 318,100 | |||||||||||||||||||||||||
39,100 | 46.39 | 2/20/2029 | 152,881 | |||||||||||||||||||||||||
34,000 | 60.03 | 2/19/2030 | | |||||||||||||||||||||||||
41,900 | 51.12 | 2/17/2031 | | |||||||||||||||||||||||||
31,500 | 58.26 | 2/15/2032 | | |||||||||||||||||||||||||
30,900 | 54.64 | 2/26/2033 | |
(1) | Option-based awards include both vested and unvested options. |
(2) | The value of all unexercised option-based awards was calculated using a December 29, 2023 closing share price of $50.30. |
(3) | Unvested share-based awards include PSUs, RSUs and any additional PSUs and RSUs from dividend reinvestment relating to such grants as of December 31, 2023. |
(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 2023 ($48.09). |
(5) | These figures represent only vested DSUs, as PSUs and RSUs are paid out upon vesting, and are based on the average closing share price for the last 50 trading days of 2023 ($48.09). |
96 | EMERA INCORPORATED |
Notice of Annual Meeting of Common Shareholders and Management Information Circular
Incentive Plan Awards Value Vested or Earned During the Year
The following table describes all option-based awards, share-based awards and non-equity incentives that vested, or were earned, during 2023 for each NEO:
Name |
Option-based awards value vested during 2023 ($) (1) |
Share-based awards (PSUs and RSUs) value vested during 2023 ($) (2) |
Non-equity incentive plan compensation value earned during the year ($) (3) |
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Scott Balfour |
653,148 | 4,191,907 | 1,308,615 | |||||||||
Greg Blunden |
152,354 | 980,750 | 572,880 | |||||||||
Archibald Collins |
27,923 | 476,266 | 520,944 | |||||||||
Karen Hutt |
70,486 | 561,032 | 432,548 | |||||||||
Bruce Marchand |
114,088 | 652,297 | 440,633 |
(1) | Represents the aggregate dollar value that would have been realized if stock options had been exercised on the applicable vesting (eligibility) date in 2023. |
(2) | The value of PSUs and RSUs vested in 2023 is based on the 2021 PSU and RSU grants, which both had three-year vesting periods from January 1, 2021 to December 31, 2023. The payout is calculated based on the original grant with accumulated dividends, multiplied by the performance factor (only applied to PSUs), multiplied by the average closing share price for the last 50 trading days of 2023 ($48.09). The performance factor for the 2021 PSU grant was based on Emeras growth in EPS and cash flow over the three-year performance and vesting period as well as Emeras TSR relative to the TSR of the S&P/TSX Capped Utilities Index. The performance factor result was 100 per cent. More details on the PSU Plan and results can be found in the section Performance Share Unit Plan. |
(3) | This amount represents the 2023 incentive payouts as disclosed in the NEO Summary Compensation Table and includes any amounts that were deferred into DSUs. |
Aggregate Option Exercise During 2023 and 2023 Option Values
The following table summarizes the number of common shares, if any, each NEO acquired pursuant to the exercise of stock options in 2023, the aggregate value realized upon exercise, and the number of common shares covered by unexercised options under the Stock Option Plan as of December 31, 2023. 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 29, 2023, which was $50.30.
Unexercised options at December 31, 2023 |
Value of unexercised in-the-money options at December 31, 2023 |
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Name |
Securities acquired on exercise (#) |
Aggregate value realized ($) |
Exercisable (#) | Unexercisable (#) | Exercisable ($) | Unexercisable ($) | ||||||||||||||||||
Scott Balfour |
| | 910,755 | 557,045 | 4,126,598 | | ||||||||||||||||||
Greg Blunden |
| | 142,020 | 128,480 | 435,025 | | ||||||||||||||||||
Archibald Collins |
| | 20,700 | 68,800 | | | ||||||||||||||||||
Karen Hutt |
| | 93,595 | 83,680 | 315,839 | | ||||||||||||||||||
Bruce Marchand |
| | 183,615 | 85,550 | 787,169 | |
Pension Plan Benefits
The Company 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 operating companies 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 or a defined contribution basis. For 2023, four NEOs participated in the defined benefit component of the Pension Plan and two NEOs participated in the defined contribution component of the Pension Plan.
EMERA INCORPORATED | 97 |
Notice of Annual Meeting of Common Shareholders and Management Information Circular
Defined Benefit
The following table shows years of credited service, estimated pension amounts and changes to accrued obligations from January 1, 2023 to December 31, 2023 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) |
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Scott Balfour (4) |
11.7 | 366,503 | 542,733 | 3,952,907 | 261,305 | 792,066 | 5,006,278 | |||||||||||||||||||||
Greg Blunden (5) |
1.3 | 20,574 | 20,574 | 567,671 | 10,805 | 59,226 | 637,702 | |||||||||||||||||||||
Bruce Marchand |
12.0 | 161,107 | 161,107 | 2,026,051 | 96,600 | 203,068 | 2,325,719 | |||||||||||||||||||||
Archibald Collins |
33.6 | 332,344 | 346,397 | 5,600,155 | 356,511 | 822,948 | 6,779,614 |
(1) | All NEOs were eligible for an immediate pension at year-end, subject to applicable reductions determined by the Pension Plans official plan text. The amount shown is the accrued pension starting at the NEOs unreduced retirement date if the NEO terminated employment on December 31, 2023. |
(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 managements best estimate of future events that affect the cost of pensions, including assumptions about future salary adjustments and short-term incentive awards. |
(4) | The accrued obligation at year-end 2022 for Mr. Balfour was revised from $3,965,968 to $3,952,907, which is shown as the accrued obligation at the start of year 2023, in the above table. |
(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 2023.
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 2023 were driven largely by changes in actuarial assumptions as well as interest on the accrued obligation and current service cost. The assumption changes from December 31, 2022 to December 31, 2023 were a change in the discount rate from 5.17 per cent to 4.63 per cent for the Pension Plan,
5.17 per cent to 4.63 per cent for the Supplementary Retirement Plan, and 5.13 per cent to 4.61 per cent for the retirement award. The net effect of the discount rate change is an increase in obligations.
The defined benefit component of the Pension Plan entitles members to pension benefits based on two per cent of the average of the members five highest years of pensionable earnings, multiplied by each year of credited service to a maximum of 35 years credited service. For the NEOs, pensionable earnings include base salary plus up to 50 per cent of their target short-term incentive. Upon a member reaching age 65, pension benefits under the Pension Plan are reduced by an amount approximately equal to the amount payable under the Canada Pension Plan. For members who retire from active service, the pension is payable on an unreduced basis upon the earlier of age 60 or age 55, provided that age and years of service add to at least 85. For members who joined the Pension Plan on or after July 1, 2004, the age 60 unreduced retirement age condition is replaced by age 62 with 15 years of service. A member may also retire on a reduced formula if the member has attained age 55, but does not qualify for an unreduced pension. Spousal benefits are paid on the death of a member at the rate of 60 per cent of regular pension benefits. Pensions are indexed to the consumer price index, subject to certain limits.
98 | EMERA INCORPORATED |
Notice of Annual Meeting of Common Shareholders and Management Information Circular
Under the terms of Mr. Balfours employment agreement, his average five highest years of pensionable earnings is capped at $1.75 million for purposes of calculating his pension.
For 2023, members of the defined benefit component of the plan contributed 7.4 per cent of eligible earnings up to the years maximum pensionable earnings (YMPE) under the Canada Pension Plan, and 9.5 per cent of earnings between the YMPE and the amount on which pension benefits may be earned under a registered pension plan as permitted by the Income Tax Act (Canada).
Due to Canada Revenue Agency limitations on the maximum pension benefit that may be paid under the Pension Plan, a portion of the pension the NEOs earned after January 1, 1992 is provided under the terms of 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.
The defined benefit component of the Pension Plan was closed to new non-union employees hired after January 8, 2013 and to new union employees hired after October 31, 2014. The defined benefit component of the Supplementary Retirement Plan was closed to new entrants as of December 31, 2017. Any employees who become eligible to participate in the Supplementary Retirement Plan after December 31, 2017 will participate in the defined contribution component.
The compensatory and non-compensatory change figures for Mr. Blunden and Mr. Collins include the increase in value of a potential retirement award. Certain employees of the Company hired before August 1, 2007 are eligible for a retirement award if they continue working with the Company until their unreduced retirement date. The retirement award is calculated by multiplying the employees weekly base salary immediately preceding retirement by the employees number of years of service at retirement, to a maximum of 26 weeks of salary, and is payable as a lump sum on retirement. If the employee terminates employment with the Company prior to his or her unreduced retirement date, no retirement award is payable. Mr. Blunden and Mr. Collins will be entitled to the retirement award if they continue working for an Emera company until their respective unreduced retirement date. Mr. Balfour and Mr. Marchand are not eligible for a retirement award.
Defined Contribution
The following table shows the changes to accumulated value from January 1, 2023 to December 31, 2023 for the NEOs 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) |
1,329,457 | 86,990 | 171,167 | 1,587,614 | ||||||||||||
Karen Hutt (4) |
1,018,209 | 55,611 | 111,530 | 1,185,351 |
(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. |
(4) | The compensatory and non-compensatory change figures for Ms. Hutt include the increase in value of a potential defined benefit retirement award, as described in the section above this table. Ms. Hutt will be entitled to the retirement award if she continues working for an Emera company until her unreduced retirement date. The accumulated values at the start and end of the year also include this potential retirement award. |
Under the defined contribution component of the Pension Plan, the Company contributes a base amount of three per cent of the participants eligible earnings into the participants 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 participants defined contribution account, factoring in the base amount and the matching contribution, is six per cent of the participants eligible earnings. Canada Revenue Agency limits apply to the total contribution that can be made under the defined contribution component and, as with the defined benefit component, a portion of the pension an NEO earns in the defined contribution component may be provided under the terms of a Supplementary Retirement Plan.
EMERA INCORPORATED | 99 |
Notice of Annual Meeting of Common Shareholders and Management Information Circular
Mr. Blunden and Ms. Hutt participated in the defined contribution component of the Pension Plan in 2023. They and the Company each contributed six per cent of their base salary into the Pension Plan up to the total amount permitted under the Income Tax Act, which equated to $15,780 each in 2023. 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 2023, the additional Company contribution for Mr. Blunden was $71,210 and for Ms. Hutt was $32,571.
Upon ending active employment with the Company at any age between 55 and 65, plan participants in the defined contribution component of the Pension Plan may start receiving retirement income through the purchase of a life annuity or by converting their account to a life income fund.
The defined contribution component of the Pension Plan is administered on behalf of the Company by a major Canadian insurance company, which acts in accordance with the provisions of the defined contribution component of the Pension Plan, the Income Tax Act and the Nova Scotia Pension Benefits Act.
Deferred Share Unit Plan
The Deferred Share Unit (DSU) Plan is another component of Emeras 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 Emeras common shares, each participants 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 operating companies. When redeemed, the value of a participants 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 participants 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 participants DSUs is calculated by multiplying the number of DSUs in the participants 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 2023.
2023 DSU Plan Allocations
The table below identifies how much of the short-term incentive for 2023 that each NEO elected to allocate to DSUs:
Name |
Percentage of 2023 annual incentive elected to deferred share units (%) |
Dollar amount of 2023 annual incentive elected to deferred share units ($) (1) |
||||||
Scott Balfour |
50 | 654,308 | ||||||
Greg Blunden |
50 | 286,440 | ||||||
Archibald Collins |
0 | 0 | ||||||
Karen Hutt |
0 | 0 | ||||||
Bruce Marchand |
0 | 0 |
(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. |
100 | EMERA INCORPORATED |
Notice of Annual Meeting of Common Shareholders and Management Information Circular
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 operating companies to purchase Emera common shares through regular payroll deductions or lump-sum payments. Participants can contribute up to $20,000 CAD/$15,000 USD per year, and the Company will match 20 per cent on employee contributions up to the contribution limit. The purchase price of the common shares under the Plan is the average of the daily high and low board lot trading price on the TSX for the five trading days prior to the purchase date. At Emeras 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 2,248,392 common shares that remain available for issuance under the Employee Common Share Purchase Plan, which represents approximately 0.82 per cent of the weighted average total issued and outstanding common shares of the Company in 2023.
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.
2023 (%) | 2022 (%) | 2021 (%) | ||||||||||
Burn rate |
||||||||||||
(number of common shares granted in a fiscal year, divided by the weighted average total number of shares outstanding) |
0.18 | 0.15 | 0.16 |
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 that require shareholder approval under this paragraph. |
The maximum number of shares issuable to insiders of the Company under all security-based compensation arrangements (including the Stock Option Plan and the Plan) at any time is 10 per cent of the issued and outstanding shares of the Company. The maximum number of shares issued to insiders, within any one-year period, under all security-based compensation arrangements, will not exceed 10 per cent of the issued and outstanding shares of the Company.
The benefits under the Plan are not assignable, and if a Plan participant ceases to be an employee of an Emera Company, their eligibility to participate in the Plan ceases.
EMERA INCORPORATED | 101 |
Notice of Annual Meeting of Common Shareholders and Management Information Circular
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, 2023. Incremental benefits in connection with a change of control are realized only in the event of a termination of employment following a change of control and no incremental benefit is realized solely on a change of control.
Name |
Departure scenario (1) |
Cash severance ($) |
Short-term incentive ($) |
Performance share units (PSUs) ($) (2) |
Restricted share units (RSUs) ($) (2) |
Stock options ($) (3) |
Continuation of benefits (present value) ($) (4) |
Total ($) | ||||||||||||||||||||||
Scott Balfour |
Resignation | | | | | | | | ||||||||||||||||||||||
Termination for cause |
| | | | | | | |||||||||||||||||||||||
Termination without cause |
2,266,000 | 2,266,000 | | | | 5,986 | 4,537,986 | |||||||||||||||||||||||
Control change |
2,266,000 | 2,266,000 | 5,377,780 | 2,688,754 | | 5,986 | 12,604,520 | |||||||||||||||||||||||
Retirement |
| | | | | | | |||||||||||||||||||||||
Greg Blunden |
Resignation | | | | | | | | ||||||||||||||||||||||
Termination for cause |
| | | | | | | |||||||||||||||||||||||
Termination without cause |
930,000 | 744,000 | | | | 7,617 | 1,681,617 | |||||||||||||||||||||||
Control change |
930,000 | 744,000 | 1,255,226 | 627,519 | | 7,617 | 3,564,362 | |||||||||||||||||||||||
Retirement |
| | | | | | | |||||||||||||||||||||||
Archibald Collins |
Resignation | | | | | | | | ||||||||||||||||||||||
Termination for cause |
| | | | | | | |||||||||||||||||||||||
Termination without cause |
900,000 | 720,000 | | | | 3,880 | 1,623,880 | |||||||||||||||||||||||
Control change |
900,000 | 720,000 | 774,105 | 387,235 | | 3,880 | 2,785,220 | |||||||||||||||||||||||
Retirement |
| | | | | | | |||||||||||||||||||||||
Karen Hutt |
Resignation | | | | | | | | ||||||||||||||||||||||
Termination for cause |
| | | | | | | |||||||||||||||||||||||
Termination without cause |
802,500 | 561,750 | | | | 2,207 | 1,366,457 | |||||||||||||||||||||||
Control change |
802,500 | 561,750 | 880,018 | 440,471 | | 2,207 | 2,686,946 | |||||||||||||||||||||||
Retirement |
| | | | | | | |||||||||||||||||||||||
Bruce Marchand |
Resignation | | | | | | | | ||||||||||||||||||||||
Termination for cause |
| | | | | | | |||||||||||||||||||||||
Termination without cause |
817,500 | 572,250 | 400,718 | 200,215 | | 1,755 | 1,992,438 | |||||||||||||||||||||||
Control change |
817,500 | 572,250 | 814,981 | 407,351 | | 1,755 | 2,613,837 | |||||||||||||||||||||||
Retirement |
| | | | | | |
(1) | Please see the tables following for a description of the entitlements of each NEO under the various departure scenarios. |
(2) | Payouts for PSUs assume a performance factor of 1.0 and both PSUs and RSUs are valued using the average closing share price for the last 50 trading days of 2023 ($48.09). |
(3) | Stock options are valued using the closing share price on December 29, 2023 of $50.30. |
(4) | 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. |
102 | EMERA INCORPORATED |
Notice of Annual Meeting of Common Shareholders and Management Information Circular
The following is a summary of each NEOs entitlements on departure, based on his or her employment contract or the applicable plans as of December 31, 2023.
Scott Balfour | ||
Resignation | All unvested PSUs, RSUs and stock options are forfeited. | |
Terminated for cause | All unvested PSUs, RSUs and stock options are forfeited. | |
Terminated without cause | Entitled to a lump sum equal to 24 months compensation based upon annual salary and short-term incentive at target. Health, dental and other such benefits will be continued for up to 12 months. Unvested PSUs and RSUs are prorated to the date of termination and paid out at the end of the respective performance period, subject to the achievement of the applicable performance criteria. Unvested stock options are forfeited. | |
Change of control | If there is a change of control of the ownership of the Company, such that any one party acquires 50 per cent or more of voting securities, Mr. Balfour may elect to terminate employment for good reason, as defined below, within 24 months of the change of control, and receive 24 months compensation based upon annual salary and short-term incentive at target. Health, dental and other such benefits will be continued for up to 12 months. Unvested PSUs and RSUs that were granted prior to the change of control are deemed to vest on the termination date and are paid out assuming a performance factor of 1.0. Unvested stock options that were granted prior to the change of control are deemed to vest on the termination date and must be exercised by the earlier of: (a) six months from the termination date; and (b) 10 years from the original grant date. | |
Retirement | Mr. Balfour becomes eligible to retire with an unreduced pension as of April 30, 2027. Information regarding pension entitlement is contained in Pension Plan Benefits. PSUs and RSUs continue to be eligible to vest in full following retirement and PSUs remain subject to the applicable performance criteria. Unvested stock options will continue to vest in full and in normal course past retirement. Any stock options granted prior to 2022 must be exercised by the earlier of (a) two years from the date of retirement; and (b) 10 years from the original grant date. Stock options granted in 2022 or later will remain exercisable for the entire term of the option. |
EMERA INCORPORATED | 103 |
Notice of Annual Meeting of Common Shareholders and Management Information Circular
Greg Blunden | ||
Resignation | All unvested PSUs, RSUs and stock options are forfeited. | |
Terminated for cause | All unvested PSUs, RSUs and stock options are forfeited. | |
Terminated without cause | Entitled to a lump sum equal to 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 18 months. Unvested PSUs and RSUs are prorated to the date of termination and paid out at the end of the respective performance period, subject to the achievement of the applicable performance criteria. Unvested stock options are forfeited. | |
Change of control | If there is a change of control of the ownership of the Company, such that any one party acquires 50 per cent or more of voting securities, Mr. Blunden may elect to terminate employment for good reason (1), as defined below, within 24 months of such changes and receive 18 months compensation based upon annual salary and short-term incentive at target. Health, dental and other such benefits will be continued for up to 18 months. Unvested PSUs and RSUs that were granted prior to the change of control are deemed to vest on the termination date and are paid out assuming a performance factor of 1.0. Unvested stock options that were granted prior to the change of control are deemed to vest on the termination date and must be exercised by the earlier of: (a) six months from the termination date; and (b) 10 years from the original grant date. | |
Retirement | Mr. Blunden becomes eligible to retire with an unreduced pension as of December 31, 2024. Information regarding pension entitlement is contained in Pension Plan Benefits. PSUs and RSUs continue to be eligible to vest in full following retirement and PSUs remain subject to the applicable performance criteria. Unvested stock options will continue to vest in full and in normal course past retirement. Any stock options granted prior to 2022 must be exercised by the earlier of (a) two years from the date of retirement; and (b) 10 years from the original grant date. Stock options granted in 2022 or later will remain exercisable for the entire term of the option. |
(1) | Good reason is described as any of the following events occurring without the NEOs consent: |
| the Company materially diminishes the NEOs position, authority, duties or responsibilities; |
| the Company requires the NEO to be based at a location more than 50 km from his or her current work location or to travel to a significantly greater extent; or |
| the Company materially reduces the NEOs annual base salary or their target incentive awards. |
104 | EMERA INCORPORATED |
Notice of Annual Meeting of Common Shareholders and Management Information Circular
Archibald Collins | ||
Resignation | All unvested PSUs, RSUs and stock options are forfeited. | |
Terminated for cause |
All unvested PSUs, RSUs and stock options are forfeited. | |
Terminated without cause | Entitled to a lump sum equal to 18 months compensation based upon annual salary and short-term incentive at target. Health, dental and other such benefits will be continued for up to 18 months. Unvested PSUs and RSUs are forfeited in accordance with the applicable plan texts. Unvested stock options are forfeited. | |
Change of control | If there is a change of control of the ownership of the Company, such that any one party acquires 50 per cent or more of voting securities, Mr. Collins may elect to terminate employment for good reason (1), as defined below, within 24 months of such changes and receive 18 months compensation based upon annual salary and short-term incentive at target. Health, dental and other such benefits will be continued for up to 18 months. Unvested PSUs and RSUs that were granted prior to the change of control are deemed to vest on the termination date. The Committee has discretion to apply any performance- based requirements on PSUs. 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. Collins became eligible to retire with an unreduced pension as of September 30, 2021. Information regarding pension entitlement is contained in Pension Plan Benefits. PSUs and RSUs continue to be eligible to vest in full following retirement and PSUs remain subject to the applicable performance criteria. Unvested stock options will continue to vest in full and in normal course past retirement. Any stock options granted prior to 2022 must be exercised by the earlier of (a) two years from the date of retirement; and (b) 10 years from the original grant date. Stock options granted in 2022 or later will remain exercisable for the entire term of the option. |
(1) | Good reason is described as any of the following events occurring without the NEOs consent: |
| the Company materially diminishes the NEOs position, authority, duties or responsibilities; |
| the Company requires the NEO to be based at a location more than 50 km from his or her current work location or to travel to a significantly greater extent; or |
| the Company materially reduces the NEOs annual base salary or their target incentive awards. |
EMERA INCORPORATED | 105 |
Notice of Annual Meeting of Common Shareholders and Management Information Circular
Karen Hutt | ||
Resignation | All unvested PSUs, RSUs and stock options are forfeited. | |
Terminated for cause | All unvested PSUs, RSUs and stock options are forfeited. | |
Terminated without cause | Entitled to a lump sum equal to 18 months compensation based upon annual salary and short-term incentive at target. Health, dental and other such benefits will be continued for up to 12 months. Unvested PSUs and RSUs are prorated to the date of termination and paid out 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 Ms. Hutts employment is terminated without cause or Ms. Hutt terminates her employment for good reason (1), as defined in her employment agreement and below, within 24 months of the change of control, Ms. Hutt is entitled to receive 18 months compensation based upon annual salary and short-term incentive at target. Health, dental and other such benefits will be continued for up to 12 months. Unvested PSUs and RSUs 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 | Ms. Hutt participates in the Defined Contribution pension plan and is eligible to retire any time after age 55. Information regarding pension entitlement is contained in Pension Plan Benefits. PSUs and RSUs continue to be eligible to vest in full following retirement and PSUs remain subject to the applicable performance criteria. Unvested stock options will continue to vest in full and in normal course past retirement. Any stock options granted prior to 2022 must be exercised by the earlier of (a) two years from the date of retirement; and (b) 10 years from the original grant date. Stock options granted in 2022 or later will remain exercisable for the entire term of the option. |
(1) | Good reason is described as any of the following events occurring without the NEOs consent: |
| the Company materially diminishes the NEOs position, authority, duties or responsibilities; |
| the Company requires the NEO to be based at a location more than 50 km from his or her current work location or to travel to a significantly greater extent; or |
| the Company materially reduces the NEOs annual base salary or their target incentive awards. |
106 | EMERA INCORPORATED |
Notice of Annual Meeting of Common Shareholders and Management Information Circular
Bruce Marchand | ||
Resignation | All unvested PSUs, RSUs and stock options are forfeited. | |
Terminated for cause | All unvested PSUs, RSUs and stock options are forfeited. | |
Terminated without cause | Entitled to a lump sum equal to 18 months compensation based upon annual salary and short-term incentive at target. Health, dental and other such benefits will be continued for up to 12 months. Unvested PSUs and RSUs are prorated to the date of termination and paid out based on an estimated future value. Unvested stock options are forfeited. | |
Change of control | If there is a change of control of the ownership of the Company, such that any one party acquires 50 per cent or more of voting securities, Mr. Marchand may elect to terminate employment for good reason (1), as defined below, within 24 months of such changes and receive 18 months compensation based upon annual salary and short-term incentive at target. Health, dental and other such benefits will be continued for up to 12 months. Unvested PSUs and RSUs 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. Marchand became eligible to retire with an unreduced pension as of June 30, 2022. Information regarding pension entitlement is contained in Pension Plan Benefits. PSUs and RSUs continue to be eligible to vest in full following retirement and PSUs remain subject to the applicable performance criteria. Unvested stock options will continue to vest in full and in normal course past retirement. Any stock options granted prior to 2022 must be exercised by the earlier of (a) two years from the date of retirement; and (b) 10 years from the original grant date. Stock options granted in 2022 or later will remain exercisable for the entire term of the option. |
(1) | Good reason is described as any of the following events occurring without the NEOs consent: |
| the Company materially diminishes the NEOs position, authority, duties or responsibilities; |
| the Company requires the NEO to be based at a location more than 50 km from his or her current work location or to travel to a significantly greater extent; or |
| the Company materially reduces the NEOs annual base salary or their target incentive awards. |
EMERA INCORPORATED | 107 |
Notice of Annual Meeting of Common Shareholders and Management Information Circular
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, 2023. 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 |
3,095,604 | 51.20 | 2,753,210 | |||||||||
Employee Common Share Purchase Plan |
N/A | N/A | 2,248,392 | |||||||||
|
|
|
|
|
|
|||||||
Total |
3,095,604 | 51.20 | 5,001,602 | |||||||||
|
|
|
|
|
|
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 since the beginning of the most recently completed financial year, other than routine indebtedness 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 Emeras 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 the Audit Committee section and to Appendix D Emera Incorporated Audit Committee Charter of Emeras Annual Information Form, for the year ended December 31, 2023, available under Emeras profile on SEDAR+ at www.sedarplus.com, or by contacting the Corporate Secretary of the Company.
108 | EMERA INCORPORATED |
Notice of Annual Meeting of Common Shareholders and 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 Emeras Articles of Association, the Board shall have the following duties and responsibilities.
STRATEGIC PLANNING
The Board shall provide oversight and guidance on the strategic issues facing Emera.
The Board shall oversee a strategic planning process resulting in a strategic plan which shall be approved on an annual basis and will take into account, among other things, the opportunities and risks of the business.
The Board shall regularly consider Emeras 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 Companys financial objectives, plans and actions, including significant capital allocations and expenditures.
The Board shall review and approve all material acquisitions, dispositions, projects, business plans, and budgets.
CULTURE
The Board shall oversee managements approach to addressing Emeras Environmental, Social and Governance (ESG) impacts, risks and opportunities which are most important to its business performance and to key stakeholders.
The Board shall be comprised of a majority of independent directors as defined from time to time under applicable legislation and the rules of any stock exchange on which Emeras 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 managements creation of an integrity-based culture throughout the Company.
RISK RESPONSIBILITY
The Board shall oversee the implementation by management of appropriate systems to identify, report and manage the principal risks of Emeras business. The Board will consider Emeras risk profile and oversee Emeras 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 Emeras mitigation response to its principal risks; |
(d) | the alignment of risk management with Emeras risk profile, its strategy, and its organizational objectives, including capital and resources allocation. |
The Board shall also review Emeras annual insurance program and uninsured exposure and Emeras 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 managements processes that provide reasonable assurance of compliance with applicable legal and regulatory requirements.
EMERA INCORPORATED | 109 |
Notice of Annual Meeting of Common Shareholders and Management Information Circular
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 Companys financial statements, managements discussion and analysis (MD&A) and earnings releases prepared by management and oversee the Companys compliance with applicable audit, accounting and reporting requirements.
The Board shall review the quality and integrity of Emeras 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 Companys 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 Boards stewardship responsibilities.
110 | EMERA INCORPORATED |
www.emera.com
Exhibit 99.2
2023 Annual Report
2023 2023 ADJUSTED NET INCOME2Excluding Corporate costs Financial Highlights BY BUSINESS SEGMENT Data is as of December 31, 2023, unless otherwise indicated. 10% annualized 10-year total shareholder return $2.96 adjusted EPS1 annual 54% Florida electric 21% Canadian electric 64% 18% Gas utilities and infrastructure of adjusted net income2, 4% Other excluding Corporate costs, 3% Other electric comes from Florida $2.9B BY REVENUE TYPE invested in 2023, leading to a 10.2% annual increase in rate base 4% dividend increase in 2023 1 Adjusted earnings per share (EPS) is a non-GAAP ratio, which does not have standardized meaning under USGAAP. For more information, refer to Non-GAAP Financial Measures and Ratios in 78% Regulated electric Emeras Q4 2023 MD&A. 2 Based on 2023 adjusted net income attributable 18% Regulated gas to common shareholders (adjusted net income), excluding Corporate costs of $356 million and 4% Unregulated including holding company interest costs. Adjusted net income is a non-GAAP measure, which does not have standardized meaning under USGAAP. For more information and a reconciliation to the nearest GAAP measure, refer to Non-GAAP Financial Measures and Ratios in Emeras Q4 2023 MD&A.
Why Invest With our proven strategy and portfolio of high-quality, regulated utilities, Emera is well positioned to continue delivering cleaner, more reliable energy for our customers in Emera while also providing our shareholders with long-term growth in earnings, cash flow and dividends. STRONG RECORD OF EFFECTIVE AND DIVIDEND GROWTH COLLABORATIVE REGULATORY ENVIRONMENTS capital investment plan1 through 2026, since 2000 Highly rated with $5.4B+ committed to decarbonization years excluding Corporate costs, derived from our of CapEx plan regulated utilities through 2026 is 2 yield the fastest-growing US state STRONG, SUSTAINABLE STRATEGY 47% 18% $12M rate-base growth reduction in CO2 of Board Director invested in through 2026 emissions4, and 77% Nominees for 2024 our communities reduction in coal identify as members of in 2023 use5, since 2005 a diverse group, other than gender60.25 Lost Time down 11% from 2022 (0.28) and a 24% Injury Rate improvement over 5-year average (0.33) 1 Emeras capital investment plan includes $240 million equity investment in 2024. 2 Based on December 29, 2023, share price of $50.30. 3 Based on 2023 adjusted net income, excluding Corporate costs of $356 million and including holding company interest costs. Adjusted net income is a non-GAAP measure, which does not have a standardized meaning under USGAAP. For more information and a reconciliation to the nearest GAAP measure, refer to Non-GAAP Financial Measures and Ratios in Emeras Q4 2023 MD&A. 4 Undergoing final review and verification 5 As a percentage of total GWh generated compared to 2005 levels. Just 13 per cent of energy generated across Emera comes from coal. 6 One Director Nominee identifies as a racialized person and one Director Nominee identifies as a member of the LGBTQ2SI+ community.
Emera at From our origins as a single electric utility, Emera has grown into an energy leader serving customers in Canada, the US and the Caribbean. Our companies a Glance include electric and natural gas utilities, gas pipelines, and energy marketing and trading operations. Data is as of December 31, 2023, unless otherwise indicated. HIGHLIGHTS NET INCOME1 ADJUSTED Excluding Corporate costs $39B BY GEOGRAPHY total assets $7.6B revenue 7,300 employees 2.5M customers 64% Florida 28% Canada 6 5% New Mexico electric and natural 3% Caribbean gas utilities 1 Based on 2023 adjusted net income, excluding Corporate costs of $356 million and including holding company interest costs. Adjusted net income is a non-GAAP measure, which does not have a standardized meaning under USGAAP. For more information and a reconciliation to the nearest GAAP measure, refer to Non-GAAP Financial Measures and Ratios in Emeras Q4 2023 MD&A.
OUR PURPOSE Energizing modern life and delivering a cleaner energy future for all. OUR OUR VISION To be the energy provider of choice for our customers, the STRATEGY employer of choice for our people and a preferred choice for investors. Were focused on safely delivering OUR VALUES cleaner, reliable Our core values shape our culture and guide our work energy at a pace every day. thats balanced We put safety above all else. with the cost We put customers at the centre of everything we do. impacts for We value candour, respect and collaboration. our customers. We care for each other, the environment and our communities. We set a high bar and take on big things. OUR CLIMATE COMMITMENT The team across Emera is working together to meet our Climate Commitment goals1 and our vision to achieve net-zero CO2 emissions by 2050. 2023 PROGRESS 2025 GOAL 2040 GOAL 2050 VISION 47% reduction in 55% reduction 80% reduction in CO2 Net-Zero CO2 emissions and 77% in CO2 emissions emissions and last coal unit CO2 emissions 2 reduction in coal use retired no later than 2040 1 Our Climate Commitment goals are compared to 2005 levels. Achieving our climate goals on these timelines is subject to external factors beyond our control, including government policies and regulatory decisions. 2 Still undergoing review and verification. Reduction in coal use is a percentage of total GWh generated compared to 2005 levels.
Letter from the Chair and the CEO Fellow shareholders, We are in an unprecedented time of change and of opportunity. The energy industry worldwide continues to grapple with the complexities of transitioning to cleaner energy while also meeting increasing energy demands. These new realities are amplified by the added pressures of global economic factors such as higher interest rates, increasingly unpredictable weather events and the need to balance the impacts on costs for customers. Despite these challenges, we continue to advance our strategy of safely delivering cleaner, reliable energy in a way that balances the impacts on costs for customers and we are making meaningful progress. We are investing in renewable and cleaner generation, reliability and system integrity, infrastructure modernization and expansion, and in new and emerging technologies. Our work to deliver for our customers across Emera is also driving continued value for our shareholders in the form of sustainable growth in dividends and returns over the long term. Jackie Sheppard Scott Balfour Chair, Emera Inc. President and Board of Directors CEO, Emera Inc.
The Emera Teams belief in our shared strategy and common values drives our business forward. THE CLEAN ENERGY TRANSITION Environmental Protection Agency Guidelines in the US and There are significant and competing pressures that must Clean Energy Regulations in Canada. As we navigate long- be addressed and carefully balanced in order to deliver a term capital investment decisions under these evolving policy successful energy transition. A clean energy future must constructs, we are working with governments and regulators be achieved in a way thats balanced with affordability for to add our voice to these important discussions to help inform customers and without sacrificing reliability all within a policy with the goal of developing the most effective and cost- system that was built at a time of lower energy demand and efficient path forward for customers. with different goals in mind. 2023 HIGHLIGHTS As energy policy and objectives continue to evolve, the demand We are continuing to make progress on this complex energy for cleaner, reliable energy increases and the challenges to transition, thanks to the dedicated and highly skilled members customer affordability intensify. Each of these critical forces of our team across Emera. Their belief in our shared strategy directly impacts the other affordability is challenged by the and common values drives our business forward. Last year, we need to invest in cleaner energy and reliability. While renewable reinforced this commitment by refreshing our company-wide energy is becoming increasingly cost-effective, our systems purpose, vision and values an articulation of why and how we were not built to support their intermittency, which means do what we do fortifying our commitment to delivering for we must invest in backup energy and in grid modernization our customers every day. We are working together to energize to support reliability. And all of this requires increased capital modern life and deliver a cleaner energy future for all. We investment in an environment where the cost of capital is much strive to be the energy provider of choice for customers, the higher, inevitably impacting affordability. employer of choice for our people and a preferred choice for In some cases, government policy is enabling the energy investors. We do all this by putting the needs of our customers transition, with programs such as the Inflation Reduction Act at the centre of everything we do. We collaborate and care for in the US and recent federal incentives in Canada, including each other, the environment and our communities and were Investment Tax Credits, grants and loans. Current policy not afraid to tackle big challenges, including those that arise objectives, such as the need to achieve 80 per cent renewable as we navigate the complexities of the clean energy transition. energy and close coal plants in Nova Scotia by 2030, are being Above all, we value the safety of our teams and communities. augmented with anticipated future policies, including the
We are continuing to make progress on this complex energy transition, thanks to the dedicated and highly skilled members of our team across Emera. Despite the economic headwinds faced in 2023, we safely The Maritime Link performed well, delivering almost executed on a nearly $3 billion capital program the largest 160 per cent of the contracted energy in 2023, accounting annual capital program in our history with a focus on for nearly 20 per cent of NS Powers energy requirements. decarbonization and reliability. This investment is driving The Maritime Link achieved 99.9 per cent availability for our progress toward realizing our vision to achieve net-zero 2023, putting it in the top 10 per cent of high-voltage direct CO2 emissions by 2050. As of 2023, we have reduced CO2 current links globally. emissions by 47 per cent compared to 2005 levels. Some of At Peoples Gas, the New River, Brightmark and Alliance our accomplishments across Emera in 2023 include: renewable natural gas (RNG) projects were completed in Tampa Electric brought four new solar projects into service 2023. These are now online and providing a clean, cost- in 2023, bringing total solar capacity to 1,255 MW enough effective source of energy, while also capturing methane to power more than 200,000 homes. Solar energy has that would otherwise be emitted into the atmosphere. saved Tampa Electric customers approximately $200 million New Mexico Gas was recognized by the American Gas in fuel costs over the last five years. Association for best practices on leak management. Its Tampa Electric reported its best year for reliability, setting Advanced Mobile Leak Detection technology uses lasers all-time records in four of its five main reliability metrics, that detect and analyze methane gas emissions. It uses including a 56 per cent reduction in the average duration of special software to calculate wind speeds and determine the customer outages since 2018. precise location of emissions sources, allowing the team to detect and address leaks more efficiently, reducing the risk Despite the impacts of one hurricane, record low of a safety incident. temperatures, wildfires, historic flooding and unprecedented daily lightning strikes, NS Power still improved reliability for customers in 2023. In addition to reducing the average frequency of outages over the last five years, the team also achieved a 36 per cent reduction in the duration1 of outages over the five-year average. 1 Customer Average Interruption Duration Index (CAIDI), including the impacts of major weather events
The Barbados Light & Power team achieved record reliability in 2023 with a 10 per cent improvement in intensity (a measure that considers the product of the average interruption duration and frequency rates) compared to 2022 which was their previous best-performing year. At Grand Bahama Power, the team signed three Independent Power Purchase Agreements to add 14.5 MW of solar to its mix in 2024, while also continuing to advance the development of 5MW of additional solar to be added to its generation fleet in 2025. New rates came into effect in two of our utilities in January 2023. At Peoples Gas, the increase is helping us continue to deliver safe, reliable natural gas service to an expanding customer base. At NS Power, the new rate is helping us meet the growing demand for electricity, strengthen reliability and protect our systems against increasingly severe weather as we work to meet government targets for moving off of coal generation. As we continue working to meet our climate objectives, more than 60 per cent of our $9 billion capital plan through 2026 will be invested in cleaner energy and reliability initiatives across the business. SAFETY The safety of our teams, customers and communities always comes first. We work to continually improve as we strive for an Emera thats predictably safe and where team members are empowered to speak up for safety and know they should only perform a task if theyre certain it can be done safely. And 2023 was no exception as we continued to improve on our overall safety performance in the past year. Our lost time injury rate improved by 24 per cent compared to our average over the last five years, achieving our best-ever level of safety performance. Our strong safety culture is underpinned by effective safety leadership and robust safety programs. In 2023, we placed even greater focus on reinforcing leadership safety by setting a goal for 75 per cent of the corporate senior management team to complete at least one safety engagement every six months. We were pleased to surpass this goal, achieving 86 per cent. While we are proud of our achievements in 2023, we know our work to keep each other safe each and every day is never complete.
FINANCIAL RESULTS
For 2023, we reported annual adjusted earnings1 of $809 million and adjusted earnings per share (EPS)1 of $2.96. Adjusted EPS in 2023 was down approximately two per cent from 2022, which was a record earnings year for Emera when you adjust for the $45 million after-tax earnings impact of a litigation settlement received in Q4 2022.
This decrease was primarily due to the impacts of higher interest rates and unfavourable weather conditions in Florida. While our annual results for 2023 were down year-over-year, we continue to build long-term value for our shareholders. We raised our dividend by four per cent in 2023, continuing our more than 17-year history of growing our dividend. And weve delivered annualized dividend growth of 5.4 per cent since 2000.
Across the energy industry, 2023 was not a good year for North American utility stock total returns. In Canada, the TSX Capped Utilities Index underperformed by 11.6 per cent compared to the broader TSX Index. In the US, the utilities index delivered its worst performance in 50 years compared to the S&P 500.
Emeras Total Shareholder Return (TSR) for 2023 was 2.5 per cent, which outperformed both the Canadian and US utility indices. Over the longer term, we delivered 10 per cent annualized TSR over the last 10 years.
With demand for clean, reliable energy on the rise, the drivers for growth remain strong, evidenced by our forecasted 7-8 per cent rate-base growth CAGR over the next three years, as we invest to meet the demands of our customers. We are confident that as we make these customer- focused investments, and as we work to continue to improve our balance sheet, we will also deliver long-term value for Emeras shareholders.
BOARD CHANGES
We would like to acknowledge long-time Director Andrea Rosen who is stepping down from the Emera Board this year. Since joining the Board in 2007, her leadership experience, financial acumen and experience and knowledge of investment and commercial banking have been of great benefit to Emera. We thank Andrea for her many contributions and wish her continued success.
We are pleased to welcome Brian Porter to the Board. Brian is the former President and Chief Executive Officer of the Bank of Nova Scotia (Scotiabank). His extensive expertise in capital markets and corporate strategy, as well as his experience in driving growth and leading a public company, will bring significant value. Welcome, Brian.
1 | Adjusted net income and adjusted EPS are non-GAAP measures, which do not have standardized meaning under USGAAP. For more information and a reconciliation to the nearest GAAP measure, refer to Non-GAAP Financial Measures and Ratios in Emeras Q4 2023 MD&A. |
8 | EMERA 2023 ANNUAL REPORT |
Financial Review
Forward-looking Information |
11 | |
Introduction and Strategic Overview |
11 | |
Non-GAAP Financial Measures and Ratios |
13 | |
Consolidated Financial Review |
15 | |
Significant Items Affecting Earnings |
15 | |
Consolidated Financial Highlights |
15 | |
Consolidated Income Statement |
||
Highlights |
17 | |
Business Overview and Outlook |
19 | |
Florida Electric Utility |
19 | |
Canadian Electric Utilities |
20 | |
Gas Utilities and Infrastructure |
24 | |
Other Electric Utilities |
25 | |
Other |
26 | |
Consolidated Balance Sheet Highlights |
27 | |
Other Developments |
28 | |
Financial Highlights |
28 | |
Florida Electric Utility |
28 | |
Canadian Electric Utilities |
29 | |
Gas Utilities and Infrastructure |
32 | |
Other Electric Utilities |
34 | |
Other |
35 |
Liquidity and Capital Resources | 37 | |
Consolidated Cash Flow Highlights |
38 | |
Working Capital |
39 | |
Contractual Obligations |
39 | |
Forecasted Consolidated |
||
Capital Expenditures |
40 | |
Debt Management |
40 | |
Credit Ratings |
42 | |
Guaranteed Debt |
42 | |
Outstanding Stock Data |
43 | |
Pension Funding | 44 | |
Off-Balance Sheet Arrangements | 44 | |
Dividend Payout Ratio | 45 | |
Transactions with Related Parties | 45 | |
Enterprise Risk and Risk Management | 46 | |
Risk Management including Financial | ||
Instruments | 57 | |
Disclosure and Internal Controls | 59 | |
Critical Accounting Estimates | 59 | |
Changes in Accounting Policiesand Practices |
63 | |
Future Accounting Pronouncements |
63 | |
Summary of Quarterly Results | 64 | |
Management Report | 65 | |
Independent Auditors Report | 66 | |
Report of Independent Registered | ||
Public Accounting Firm | 70 | |
Consolidated Financial Statements | 73 | |
Notes to the Consolidated | ||
Financial Statements | 79 | |
Emera Leadership and Board | 139 | |
Shareholder Information | 140 |
EMERA 2023 ANNUAL REPORT | 9 |
Managements Discussion & Analysis
As at February 26, 2024
Managements Discussion & Analysis (MD&A) provides a review of the results of operations of Emera Incorporated and its consolidated subsidiaries and investments (collectively referred to as Emera or the Company) during the fourth quarter of, and for the full year of, 2023 relative to the same periods in 2022 and selected financial information for 2021; and its financial position as at December 31, 2023 relative to December 31, 2022. The Companys activities are carried out through five reportable segments: Florida Electric Utility, Canadian Electric Utilities, Gas Utilities and Infrastructure, Other Electric Utilities, and Other.
This MD&A should be read in conjunction with the Emera annual audited consolidated financial statements and supporting notes as at and for the year ended December 31, 2023. Emera follows United States Generally Accepted Accounting Principles
(USGAAP or GAAP). Additional information related to Emera, including the Companys Annual Information Form can be found on Sedar+ at www.sedarplus.ca.
The accounting policies used by Emeras rate-regulated entities may differ from those used by Emeras non-rate-regulated businesses with respect to the timing of recognition of certain assets, liabilities, revenues and expenses. At December 31, 2023, Emeras rate-regulated subsidiaries and investments include:
Emera Rate-Regulated Subsidiary or Equity Investment Subsidiary | Accounting Policies Approved/Examined By | |
Tampa Electric Company (TEC) (1) | Florida Public Service Commission (FPSC) and the Federal Energy Regulatory Commission (FERC) | |
Nova Scotia Power Inc. (NSPI) | Nova Scotia Utility and Review Board (UARB) | |
Peoples Gas System, Inc. (PGS) (1) | FPSC | |
New Mexico Gas Company, Inc. (NMGC) | New Mexico Public Regulation Commission (NMPRC) | |
SeaCoast Gas Transmission, LLC (SeaCoast) | FPSC | |
Emera Brunswick Pipeline Company Limited (Brunswick Pipeline) | Canadian Energy Regulator (CER) | |
Barbados Light & Power Company Limited (BLPC) | Fair Trading Commission, Barbados (FTC) | |
Grand Bahama Power Company Limited (GBPC) | The Grand Bahama Port Authority (GBPA) | |
Equity Investments | ||
NSP Maritime Link Inc. (NSPML) | UARB | |
Labrador Island Link Limited Partnership (LIL) | Newfoundland and Labrador Board of Commissioners of Public Utilities | |
Maritimes & Northeast Pipeline Limited Partnership and Maritimes & Northeast Pipeline, LLC (M&NP) | CER and FERC | |
St. Lucia Electricity Services Limited (Lucelec) | National Utility Regulatory Commission |
(1) | Effective January 1, 2023, Peoples Gas System ceased to be a division of TEC and the gas utility was reorganized, resulting in a separate legal entity called Peoples Gas System, Inc., a wholly owned direct subsidiary of TECO Gas Operations, Inc. |
All amounts are in Canadian dollars (CAD), except for the Florida Electric Utility, Gas Utilities and Infrastructure, and Other Electric Utilities sections of the MD&A, which are reported in United States dollars (USD) unless otherwise stated.
10 | EMERA 2023 ANNUAL REPORT |
Managements Discussion & Analysis
Forward-looking Information
This MD&A contains forward-looking information (FLI) and statements which reflect the current view with respect to the Companys expectations regarding future growth, results of operations, performance, carbon dioxide emissions reduction goals, business prospects and opportunities, and may not be appropriate for other purposes within the meaning of applicable Canadian securities laws. All such information and statements are made pursuant to safe harbour provisions contained in applicable securities legislation. The words anticipates, believes, budget, could, estimates, expects, forecast, intends, may, might, plans, projects, schedule, should, targets, will, would and similar expressions are often intended to identify FLI, although not all FLI contains these identifying words. The FLI reflects managements current beliefs and is based on information currently available to Emeras 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 FLI 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 FLI. Factors that could cause results or events to differ from current expectations include, without limitation: regulatory and political risk; operating and maintenance risks; changes in economic conditions; commodity price and availability risk; liquidity and capital market risk; changes in credit ratings; future dividend growth; timing and costs associated with certain capital investments; expected impacts on Emera of challenges in the global economy; estimated energy consumption rates; maintenance of adequate insurance coverage; changes in customer energy usage patterns; developments in technology that could reduce demand for electricity; global climate change; weather risk, including higher frequency and severity of weather events; risk of wildfires; unanticipated maintenance and other expenditures; system operating and maintenance risk; derivative financial instruments and hedging; interest rate risk; inflation risk; counterparty risk; disruption of fuel supply; country risks; supply chain risk; environmental risks; foreign exchange (FX); regulatory and government decisions, including changes to environmental legislation, financial reporting and tax legislation; risks associated with pension plan performance and funding requirements; loss of service area; risk of failure of information technology (IT) infrastructure and cybersecurity risks; uncertainties associated with infectious diseases, pandemics and similar public health threats; market energy sales prices; labour relations; and availability of labour and management resources.
Readers are cautioned not to place undue reliance on FLI, as actual results could differ materially from the plans, expectations, estimates or intentions and statements expressed in the FLI. All FLI 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 FLI as a result of new information, future events or otherwise.
Introduction and Strategic Overview
Based in Halifax, Nova Scotia, Emera owns and operates cost-of-service rate-regulated electric and gas utilities in Canada, the United States (US) and the Caribbean. Cost-of-service utilities provide essential electric and gas services in designated territories under franchises and are overseen by regulatory authorities. Emeras strategic focus continues to be safely delivering cleaner, affordable and reliable energy to its customers.
The majority of Emeras investments in rate-regulated businesses are located in Florida with other investments in Nova Scotia, New Mexico and the Caribbean. Emeras portfolio of regulated utilities provides reliable earnings, cash flow and dividends. Earnings opportunities in regulated utilities are generally driven by the magnitude of net investment in the utility (known as rate base), and the amount of equity in the capital structure and the return on that equity (ROE) as approved through regulation. Earnings are also affected by sales volumes and operating expenses.
Emeras capital investment plan is approximately $9 billion over the 2024 through 2026 period with approximately $2 billion of additional potential capital investments over the same period. The capital investment plan and additional potential capital result in an anticipated compound annual rate base growth in the range of approximately 7 per cent to 8 per cent through 2026. The capital investment plan includes significant investments across the portfolio in renewable and cleaner generation, reliability and system integrity investments, infrastructure modernization, infrastructure expansion to meet the needs of new and existing customers, and technologies to better support the business and customer experiences. It is anticipated that approximately 75 per cent of Emeras $9 billion capital investment plan over the 2024 through 2026 period will be made in Florida.
EMERA 2023 ANNUAL REPORT | 11 |
Managements Discussion & Analysis
Emeras capital investment plan is being funded primarily through internally generated cash flows, debt raised at the operating company level consistent with regulated capital structures, equity, and select asset sales. Generally, equity requirements in support of the Companys capital investment plan are expected to be funded through the issuance of preferred equity and the issuance of common equity through Emeras dividend reinvestment plan (DRIP) and at-the-market program (ATM program). Maintaining investment-grade credit ratings is a priority of the Company.
Emera has provided annual dividend growth guidance of four to five per cent through 2026. The Company targets a long-term dividend payout ratio of adjusted net income of 70 to 75 per cent and, while the payout ratio is likely to exceed that target through and beyond the forecast period, it is expected to return to that range over time. For further information on the non- GAAP measure Dividend Payout Ratio of Adjusted Net Income, refer to the Non-GAAP Financial Measures and Ratios section.
Seasonal patterns and other weather events affect demand and operating costs. Similarly, mark-to-market (MTM) adjustments and foreign currency exchange can have a material impact on financial results for a specific period. Emeras consolidated net income and cash flows are impacted by movements in the USD relative to the CAD. Emera may hedge both transactional and translational exposure. These impacts, as well as the timing of capital investments and other factors, mean 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 experiencing significant change and Emera is well-positioned to continue to respond to shifting customer demands and meet the challenges of digitization, decarbonization and decentralized generation, within complex regulatory environments.
Customers depend on energy and are looking for more choice, better control, and greater reliability. The costs of decentralized generation and storage have become more competitive and advancing technologies are transforming how utilities operate and interact with customers. Concurrently, climate change and the increased frequency of extreme weather events are shaping government energy policy. This is also creating a need to replace aging infrastructure and make investments to protect and harden energy systems to deliver energy reliability and system resiliency. These factors combined with inflation, higher interest rates and higher cost of capital place increased pressure on energy costs, and thus customer rates, at a time when affordability is a challenge.
Emeras strategy is centered on delivering value for customers, and in doing so creating value for shareholders. This includes:
| investing in cleaner and renewable sources of energy, in the related transmission assets, and in energy storage needed to support intermittent renewables; |
| supporting increasing demand from customers and the ongoing electrification of other sectors; |
| improving system reliability and resiliency, including replacing aging infrastructure and expanding systems to service new customers; and |
| investing in new internal and customer-facing technologies for improved cost efficiency and better customer experiences. |
Building on its decarbonization progress, Emera is continuing its efforts by establishing clear carbon reduction goals and a vision to achieve net-zero carbon dioxide emissions by 2050.
This vision is inspired by Emeras strong track record, the Companys experienced team, and a visible path to Emeras interim carbon goals. With existing technologies and resources, and subject to supportive government and regulatory decisions, Emera is working to achieve the following goals compared to corresponding 2005 levels:
| A 55 per cent reduction in carbon dioxide emissions by 2025. |
| The retirement of Emeras last existing coal unit no later than 2040. |
| An 80 per cent reduction in carbon dioxide emissions by 2040. |
Achieving the above climate goals on these timelines is subject to the Companys regulatory obligations and other external factors beyond Emeras control.
Emera seeks to deliver on its Climate Commitment while maintaining its focus on investing in reliability and staying focused on the cost impacts for customers. Emera is also committed to identifying emerging technologies and continuing to work constructively with policymakers, regulators, partners, investors and customers to achieve these goals and realize its net-zero vision.
Emera is committed to world-class safety, operational excellence, good governance, excellent customer service, reliability, being an employer of choice, and building constructive relationships.
12 | EMERA 2023 ANNUAL REPORT |
Managements Discussion & Analysis
Non-GAAP Financial Measures and Ratios
Emera uses financial measures and ratios that do not have standardized meaning under USGAAP and may not be comparable to similar measures presented by other entities. The non-GAAP measures and ratios are calculated by adjusting certain GAAP measures for specific items. Management believes excluding these items better distinguishes ongoing operations of the business and allows investors to better understand and evaluate the business. These measures and ratios are discussed and reconciled below.
Adjusted Net Income Attributable to Common Shareholders, Adjusted Earnings (Loss) Per Common Share (EPS) Basic and Dividend Payout Ratio of Adjusted Net Income
Emera calculates an adjusted net income attributable to common shareholders (adjusted net income) measure by excluding the effect of MTM adjustments, the GBPC impairment charge in 2022, and the impact of the 2022 NSPML unrecoverable costs.
Management believes excluding from net income the effect of MTM valuations and changes thereto, until settlement, better aligns the intent and financial effect of these contracts with the underlying cash flows, and therefore excludes MTM adjustments for evaluation of performance and incentive compensation. The MTM adjustments are related to the following:
| 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, and the related amortization of transportation capacity recognized as a result of certain Emera Energy marketing and trading transactions; |
| the business activities of Bear Swamp Power Company LLC (Bear Swamp) included in Emeras equity income; |
| equity securities held in BLPC and Emera Energy; and |
| FX hedges entered into to hedge USD denominated operating unit earnings exposure. |
For further detail on these MTM adjustments, refer to the Consolidated Financial Review, Financial Highlights Other Electric Utilities, and Financial Highlights Other sections.
In Q4 2022, the Company recognized a $73 million non-cash goodwill impairment charge related to GBPC due to a decline in the fair value (FV) of the reporting unit driven by the effects of macro-economic factors on the discount rate calculation. Management believes excluding from net income the effect of this charge better distinguishes ongoing operations of the business and allows investors to better understand and evaluate the Company. For further details on the GBPC impairment charge, refer to Significant Items Impacting Earnings, and Financial Highlights Other Electric Utilities sections.
In February 2022, the UARB issued a decision to disallow recovery of $9 million in costs ($7 million after-tax) included in NSPMLs final capital cost application. The after-tax unrecoverable costs were recognized in Income from equity investments in Emeras Consolidated Statements of Income. Management believes excluding these unrecoverable costs from the calculation of adjusted net income better reflects the underlying operations in the period. For further details on the 2022 NSPML unrecoverable costs, refer to the Financial Highlights Canadian Electric Utilities section.
Adjusted EPS basic and dividend payout ratio of adjusted net income are non-GAAP ratios which are calculated using adjusted net income, as described above. For further details on dividend payout ratio of adjusted net income, see the Dividend Payout Ratio section.
Emera calculates adjusted net income for the Canadian Electric Utilities, Other Electric Utilities, and Other segments. Reconciliation to the nearest GAAP measure is included in each segment. Refer to Financial Highlights Canadian Electric Utilities, Financial Highlights Other Electric Utilities and Financial Highlights Other sections.
EMERA 2023 ANNUAL REPORT | 13 |
Managements Discussion & Analysis
The following reconciles net income attributable to common shareholders to adjusted net income:
For the | Three months ended December 31 |
Year ended December 31 |
||||||||||||||||||
millions of dollars (except per share amounts) |
2023 | 2022 | 2023 | 2022 | 2021 | |||||||||||||||
Net income attributable to common shareholders |
$ | 289 | $ | 483 | $ | 978 | $ | 945 | $ | 510 | ||||||||||
MTM gain (loss), after-tax (1) |
114 | 307 | 169 | 175 | (213 | ) | ||||||||||||||
GBPC impairment charge |
| (73 | ) | | (73 | ) | | |||||||||||||
NSPML unrecoverable costs ( 2) |
| | | (7 | ) | | ||||||||||||||
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Adjusted net income |
$ | 175 | $ | 249 | $ | 809 | $ | 850 | $ | 723 | ||||||||||
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EPS basic |
$ | 1.04 | $ | 1.80 | $ | 3.57 | $ | 3.56 | $ | 1.98 | ||||||||||
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Adjusted EPS basic |
$ | 0.63 | $ | 0.93 | $ | 2.96 | $ | 3.20 | $ | 2.81 | ||||||||||
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(1) | Net of income tax expense of $44 million for the three months ended December 31, 2023 (2022 $124 million expense) and $68 million expense for the year ended December 31, 2023 (2022 $73 million expense) (2021 $86 million recovery). |
(2) | Emera accounts for NSPML as an equity investment and therefore the after-tax unrecoverable costs were recorded in Income from equity investments on Emeras Consolidated Statements of Income. |
EBITDA and Adjusted EBITDA
Earnings before interest, income taxes, depreciation and amortization (EBITDA) and adjusted EBITDA are non-GAAP financial measures used by Emera. These financial measures are used by numerous investors and lenders to better understand cash flows and credit quality. EBITDA is useful to assess Emeras operating performance and indicates the Companys ability to service or incur debt, invest in capital, and finance working capital requirements.
Similar to adjusted net income calculations described above, adjusted EBITDA represents EBITDA absent the income effect of MTM adjustments, the 2022 GBPC impairment charge and the 2022 NSPML unrecoverable costs.
The following is a reconciliation of net income to EBITDA and Adjusted EBITDA:
For the | Three months ended December 31 |
Year ended December 31 |
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millions of dollars |
2023 | 2022 | 2023 | 2022 | 2021 | |||||||||||||||
Net income (1) |
$ | 307 | $ | 499 | $ | 1,045 | $ | 1,009 | $ | 561 | ||||||||||
Interest expense, net |
241 | 206 | 925 | 709 | 611 | |||||||||||||||
Income tax expense (recovery) |
51 | 154 | 128 | 185 | (6 | ) | ||||||||||||||
Depreciation and amortization |
264 | 254 | 1,049 | 952 | 902 | |||||||||||||||
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EBITDA |
$ | 863 | $ | 1,113 | $ | 3,147 | $ | 2,855 | $ | 2,068 | ||||||||||
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MTM gain (loss), before-tax |
158 | 431 | 237 | 248 | (299 | ) | ||||||||||||||
GBPC impairment charge |
| (73 | ) | | (73 | ) | | |||||||||||||
NSPML unrecoverable costs (2) |
| | | (7 | ) | | ||||||||||||||
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Adjusted EBITDA |
$ | 705 | $ | 755 | $ | 2,910 | $ | 2,687 | $ | 2,367 | ||||||||||
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(1) | Net income is before Non-controlling interest in subsidiaries and Preferred stock dividends. |
(2) | Emera accounts for NSPML as an equity investment and therefore the after-tax unrecoverable costs were recorded in Income from equity investments on Emeras Consolidated Statements of Income. |
14 | EMERA 2023 ANNUAL REPORT |
Managements Discussion & Analysis
Consolidated Financial Review
SIGNIFICANT ITEMS AFFECTING EARNINGS
2023
Earnings Impact of MTM Gain, After-Tax
MTM gain, after-tax decreased $193 million to $114 million in Q4 2023, compared to $307 million in Q4 2022 primarily due to unfavourable changes in existing positions, partially offset by higher amortization of gas transportation assets in 2022 at Emera Energy Services (EES). For the year ended December 31, 2023, MTM gain, after-tax decreased $6 million to $169 million compared to $175 million for the same period in 2022 primarily due to higher amortization of gas transportation assets at EES, partially offset by favourable changes in existing positions at EES and gains on Corporate FX hedges.
2022
GBPC Impairment Charge
In Q4 2022, Emera recognized a goodwill impairment charge of $73 million ($0.27 per common share) for GBPC due to a decline in the FV of the reporting unit driven by the effects of macro-economic factors on discount rate calculations. This non-cash charge was recorded in GBPC Impairment charge on the Consolidated Statements of Income and reduced the GBPC goodwill balance to nil. For further details, refer to note 22 in the consolidated financial statements.
TECO Guatemala Holdings (TGH) International Arbitration and Award
In Q4 2022, a payment of $63 million ($45 million after tax and legal costs, or $0.17 per common share), was made by the Republic of Guatemala to TECO Energy in satisfaction of the second and final award issued by the International Centre of the Settlement of Investment Disputes tribunal regarding a dispute over an investment of TGH, a wholly owned subsidiary of TECO Energy. The payment was recognized in Other income, net on the Consolidated Statements of Income. For further details, refer to note 8 in the consolidated financial statements.
CONSOLIDATED FINANCIAL HIGHLIGHTS
For the millions of dollars |
Three months ended December 31 |
Year ended December 31 |
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Adjusted net income |
2023 | 2022 | 2023 | 2022 | 2021 | |||||||||||||||
Florida Electric Utility |
$ | 115 | $ | 124 | $ | 627 | $ | 596 | $ | 462 | ||||||||||
Canadian Electric Utilities |
68 | 46 | 247 | 222 | 241 | |||||||||||||||
Gas Utilities and Infrastructure |
59 | 72 | 214 | 221 | 198 | |||||||||||||||
Other Electric Utilities |
4 | 8 | 35 | 29 | 20 | |||||||||||||||
Other |
(71 | ) | (1 | ) | (314 | ) | (218 | ) | (198 | ) | ||||||||||
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Adjusted net income |
$ | 175 | $ | 249 | $ | 809 | $ | 850 | $ | 723 | ||||||||||
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MTM gain (loss), after-tax |
114 | 307 | 169 | 175 | (213 | ) | ||||||||||||||
GBPC impairment charge |
| (73 | ) | | (73 | ) | | |||||||||||||
NSPML unrecoverable costs |
| | | 7 | | |||||||||||||||
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Net income attributable to common shareholders |
$ | 289 | $ | 483 | $ | 978 | $ | 945 | $ | 510 | ||||||||||
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EMERA 2023 ANNUAL REPORT | 15 |
Managements Discussion & Analysis
The following table highlights the significant changes in adjusted net income from 2022 to 2023:
For the millions of dollars |
Three months ended December 31 |
Year ended December 31 |
||||||
Adjusted net income 2022 |
$ | 249 | $ | 850 | ||||
Operating Unit Performance |
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Increased earnings at NSPI due to new base rates and increased sales volumes, partially offset by higher operating, maintenance and general expenses (OM&G), interest expense and depreciation |
17 | 10 | ||||||
Increased income from equity investments at NSPML quarter-over-quarter primarily due to the Maritime Link holdback (the holdback) recognized in Q4 2022. Year-over-year also due to the partial reversal in Q3 2023 of the holdback recognized in 2022 |
4 | 10 | ||||||
Decreased earnings quarter-over-quarter at TEC due to increased interest expense, depreciation, state and municipal taxes, unfavourable weather, and higher OM&G, partially offset by new base rates and customer growth driving higher sales volumes. Increased earnings year-over-year due to new base rates, the impact of a weaker CAD and customer growth, partially offset by higher interest expense, depreciation, state and municipal taxes, and OM&G, and unfavourable weather |
(9 | ) | 31 | |||||
Decreased earnings quarter-over-quarter at NMGC primarily due to lower asset optimization revenues and higher OM&G, partially offset by new base rates. Increased earnings year- over-year due to new base rates, partially offset by higher OM&G and interest expense |
(11 | ) | 12 | |||||
Decreased earnings at EES due to more favourable market conditions in 2022 |
(21 | ) | (22 | ) | ||||
Corporate |
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Decreased OM&G, pre-tax, due to timing of long-term compensation and related hedges |
13 | 10 | ||||||
Increased interest expense, pre-tax, due to higher interest rates and higher debt levels |
(9 | ) | (51 | ) | ||||
Decreased income tax recovery quarter-over-quarter primarily due to the impact of effective state tax rates |
(10 | ) | 2 | |||||
TGH award, after tax and legal costs, in Q4 2022. Refer to the Significant Items Affecting Earnings section |
(45 | ) | (45 | ) | ||||
Other Variances |
(3 | ) | 2 | |||||
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Adjusted net income 2023 |
$ | 175 | $ | 809 | ||||
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For further details of reportable segments contributions, refer to the Financial Highlights section.
For the | Year ended December 31 |
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millions of dollars |
2023 | 2022 | 2021 | |||||||||
Operating cash flow before changes in working capital |
$ | 2,336 | $ | 1,147 | $ | 1,337 | ||||||
Change in working capital |
(95 | ) | (234 | ) | (152 | ) | ||||||
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Operating cash flow |
$ | 2,241 | $ | 913 | $ | 1,185 | ||||||
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Investing cash flow |
$ | (2,917 | ) | $ | (2,569 | ) | $ | (2,332 | ) | |||
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Financing cash flow |
$ | 939 | $ | 1,555 | $ | 1,311 | ||||||
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For further discussion of cash flow, refer to the Consolidated Cash Flow Highlights section.
As at | December 31 | |||||||||||
millions of dollars |
2023 | 2022 | 2021 | |||||||||
Total assets |
$ | 39,480 | $ | 39,742 | $ | 34,244 | ||||||
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Total long-term debt (including current portion) |
$ | 18,365 | $ | 16,318 | $ | 14,658 | ||||||
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16 | EMERA 2023 ANNUAL REPORT |
Managements Discussion & Analysis
CONSOLIDATED INCOME STATEMENT HIGHLIGHTS
For the millions of dollars |
Three months ended December 31 |
Year ended December 31 |
Year ended December 31 |
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(except per share amounts) |
2023 | 2022 | Variance | 2023 | 2022 | Variance | 2021 | |||||||||||||||||||||
Operating revenues |
$ | 1,972 | $ | 2,358 | $ | (386 | ) | $ | 7,563 | $ | 7,588 | $ | (25 | ) | $ | 5,765 | ||||||||||||
Operating expenses |
1,467 | 1,638 | 171 | 5,769 | 5,959 | 190 | 4,835 | |||||||||||||||||||||
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Income from operations |
$ | 505 | $ | 720 | $ | (215 | ) | $ | 1,794 | $ | 1,629 | $ | 165 | $ | 930 | |||||||||||||
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Other income, net |
$ | 51 | $ | 102 | $ | (51 | ) | $ | 158 | $ | 145 | $ | 13 | $ | 93 | |||||||||||||
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Interest expense, net |
$ | 241 | $ | 206 | $ | (35 | ) | $ | 925 | $ | 709 | $ | (216 | ) | $ | 611 | ||||||||||||
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Net income attributable to common shareholders |
$ | 289 | $ | 483 | $ | (194 | ) | $ | 978 | $ | 945 | $ | 33 | $ | 510 | |||||||||||||
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Adjusted net income |
$ | 175 | $ | 249 | $ | (74 | ) | $ | 809 | $ | 850 | $ | (41 | ) | $ | 723 | ||||||||||||
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Weighted average shares of common stock outstanding (in millions) (1) |
277.7 | 269.0 | 8.7 | 273.6 | 265.5 | 8.1 | 257.2 | |||||||||||||||||||||
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EPS basic |
$ | 1.04 | $ | 1.80 | $ | (0.76 | ) | $ | 3.57 | $ | 3.56 | $ | 0.01 | $ | 1.98 | |||||||||||||
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EPS diluted |
$ | 1.04 | $ | 1.80 | $ | (0.76 | ) | $ | 3.57 | $ | 3.55 | $ | 0.02 | $ | 1.98 | |||||||||||||
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Adjusted EPS basic |
$ | 0.63 | $ | 0.93 | $ | (0.30 | ) | $ | 2.96 | $ | 3.20 | $ | (0.24 | ) | $ | 2.81 | ||||||||||||
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Adjusted EBITDA |
$ | 705 | $ | 755 | $ | (50 | ) | $ | 2,910 | $ | 2,687 | $ | 223 | $ | 2,367 | |||||||||||||
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Dividends per common share declared |
$ | 0.7175 | $ | 0.6900 | $ | 0.0275 | $ | 2.7875 | $ | 2.6775 | $ | 0.1100 | $ | 2.5750 | ||||||||||||||
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Dividends per first preferred shares declared: |
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Series A |
$ | 0.5456 | $ | 0.5456 | $ | | $ | 0.5456 | ||||||||||||||||||||
Series B |
$ | 1.5583 | $ | 0.6869 | $ | 0.8714 | $ | 0.4873 | ||||||||||||||||||||
Series C |
$ | 1.2873 | $ | 1.1802 | $ | 0.1071 | $ | 1.1802 | ||||||||||||||||||||
Series E |
$ | 1.1250 | $ | 1.1250 | $ | | $ | 1.1250 | ||||||||||||||||||||
Series F |
$ | 1.0505 | $ | 1.0505 | $ | | $ | 1.0505 | ||||||||||||||||||||
Series H |
$ | 1.3140 | $ | 1.2250 | $ | 0.0890 | $ | 1.2250 | ||||||||||||||||||||
Series J |
$ | 1.0625 | $ | 1.0625 | $ | | $ | 0.6470 | ||||||||||||||||||||
Series L |
$ | 1.1500 | $ | 1.1500 | $ | | $ | 0.1638 | ||||||||||||||||||||
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(1) | Effective February 10, 2022, deferred share units are no longer able to be settled in shares and are therefore excluded from weighted average shares of common stock outstanding. |
Operating Revenues
For Q4 2023, operating revenues decreased $386 million compared to Q4 2022 and, excluding decreased MTM gains of $286 million, decreased $100 million. The decrease was due to lower fuel revenues at NMGC, TEC, and NSPI; decreased marketing and trading margin at EES; lower asset optimization revenue at NMGC; and unfavourable weather at TEC. These decreases were partially offset by new base rates at TEC, NSPI and NMGC; storm cost recovery surcharge revenue at TEC; customer growth at TEC and NSPI; and favourable weather at NSPI.
For the year ended December 31, 2023, operating revenues decreased $25 million compared to 2022 and, excluding decreased MTM gains of $62 million, increased $37 million. The increase was due to new base rates at TEC, NSPI and NMGC; the impact of a weaker CAD; storm cost recovery surcharge revenue at TEC; and customer growth at TEC and NSPI. These increases were partially offset by lower fuel revenues at NMGC, TEC, NSPI, PGS and BLPC; lower off-system sales at PGS; a change in fuel cost recovery methodology for an industrial customer at NSPI; and decreased marketing and trading margin at EES.
EMERA 2023 ANNUAL REPORT | 17 |
Managements Discussion & Analysis
Operating Expenses
For Q4 2023, operating expenses decreased $171 million compared to Q4 2022 and excluding the 2022 GBPC impairment charge of $73 million, decreased $98 million. For the year ended December 31, 2023, operating expenses decreased $190 million compared to 2022 and excluding the 2022 GBPC impairment charge of $73 million, decreased $117 million. The decreases in both periods were due to lower fuel expenses at TEC, NMGC, and PGS; partially offset by higher OM&G at TEC due to storm restoration costs recognized related to the storm cost recovery surcharge revenue, and at NSPI due to higher power generation and transmission and distribution field services cost. Year-over-year the decrease was also due to a change in fuel cost recovery for an industrial customer at NSPI, partially offset by the impact of a weaker CAD and the recognition of the Nova Scotia Renewable Electricity Regulations (RER) penalty at NSPI.
Other Income, net
For Q4 2023, other income, net decreased $51 million compared to Q4 2022, primarily due to the TGH award in Q4 2022. For the year ended December 31, 2023, other income, net increased $13 million compared to 2022, primarily due to increased FX gains in 2023; higher interest income primarily at TEC; and higher pension non-current service cost recovery, partially offset by the TGH award in 2022.
Interest Expense, net
Interest expense, net for Q4 2023 increased $35 million, and for the year ended December 31, 2023 increased $216 million compared to the same periods in 2022. The increases in both periods were due to higher interest rates; higher borrowings to support capital investments and ongoing operations; and the impact of a weaker CAD.
Net Income and Adjusted Net Income
Net income attributable to common shareholders for Q4 2023, compared to Q4 2022, was unfavourably impacted by the $193 million decrease in MTM gains, after-tax, and favourably impacted by the $73 million GBPC impairment charge from 2022. Excluding these changes, adjusted net income decreased $74 million. This was primarily due to the TGH award in Q4 2022; decreased earnings at EES, NMGC and TEC; lower Corporate income tax recovery; and increased Corporate interest expense. These were partially offset by increased earnings at NSPI and NSPML; and decreased Corporate OM&G due to the timing of long- term compensation and related hedges.
Net income attributable to common shareholders for the year ended 2023, as compared to the same period in 2022, was unfavourably impacted by the $6 million decrease in MTM gains, after-tax, and favourably impacted by the $73 million GBPC impairment charge and the $7 million in NSPML unrecoverable costs from 2022. Excluding these changes, adjusted net income decreased $41 million. The decrease was primarily due to increased Corporate interest expense due to higher interest rates and increased total debt; the TGH award in Q4 2022; and decreased earnings at EES. These were partially offset by increased earnings at TEC, NMGC, NSPI and NSPML.
EPS and Adjusted EPS Basic
EPS and Adjusted EPS basic were lower for Q4 2023 due to the increase in weighted average shares of common stock outstanding and decreased earnings as discussed above.
EPS basic was higher for the year ended December 31, 2023, due to the impact of higher earnings as discussed above. Adjusted EPS basic was lower for the year ended December 31, 2023 due to the increase in weighted average shares of common stock outstanding and decreased adjusted earnings, as discussed above.
18 | EMERA 2023 ANNUAL REPORT |
Managements Discussion & Analysis
Effect of Foreign Currency Translation
Emera operates in Canada, the United States and various Caribbean countries and, as such, generates revenues and incurs expenses denominated in local currencies which are translated into CAD for financial reporting. Changes in translation rates, particularly in the value of the USD against the CAD, can positively or adversely affect results.
Results of foreign operations are translated at the weighted average rate of exchange, and assets and liabilities of foreign operations are translated at period end rates. The relevant CAD/USD exchange rates for 2023 and 2022 are as follows:
Three months ended December 31 |
Year ended December 31 |
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2023 | 2022 | 2023 | 2022 | |||||||||||||
Weighted average CAD/USD |
$ | 1.36 | $ | 1.37 | $ | 1.35 | $ | 1.34 | ||||||||
Period end CAD/USD exchange rate |
$ | 1.32 | $ | 1.35 | $ | 1.32 | $ | 1.35 | ||||||||
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The table below includes Emeras significant segments whose contributions to adjusted net income are recorded in USD currency:
For the | Three months ended December 31 |
Year ended December 31 |
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millions of USD |
2023 | 2022 | 2023 | 2022 | ||||||||||||
Florida Electric Utility |
$ | 85 | $ | 91 | $ | 466 | $ | 458 | ||||||||
Gas Utilities and Infrastructure (1) |
41 | 45 | 142 | 143 | ||||||||||||
Other Electric Utilities |
3 | 7 | 26 | 23 | ||||||||||||
Other segment (2) |
(18 | ) | 30 | (95 | ) | (50 | ) | |||||||||
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Total (3) |
$ | 111 | $ | 173 | $ | 539 | $ | 574 | ||||||||
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(1) | Includes USD net income from PGS, NMGC, SeaCoast and M&NP. |
(2) | Includes Emera Energys USD adjusted net income from EES, Bear Swamp and interest expense on Emera Inc.s USD denominated debt. |
(3) | Excludes $73 million USD in MTM gain, after-tax, for the three months ended December 31, 2023 (2022 $222 million USD MTM gain, after-tax) and MTM gain, after-tax of $116 million USD for the year ended December 31, 2023 (2022 $130 million USD MTM gain, after-tax) and the GBPC impairment charge of nil for the three months and year ended December 31, 2023 (2022 $54 million USD). |
The translation impact of the change in FX rates on foreign denominated earnings increased net income by $13 million in Q4 2023 and $46 million for the year ended December 31, 2023, compared to the same periods in 2022. The translation impact of the change in FX rates on foreign denominated earnings decreased adjusted net income by $3 million in Q4 2023 and increased adjusted net income by $20 million for the year ended December 31, 2023 compared to the same periods in 2022. Impacts
of the changes in the translation of the CAD include the impacts of Corporate FX hedges used to mitigate translation risk of USD earnings in the Other segment.
Business Overview and Outlook
Emeras 2023 results were impacted by macroeconomic conditions, specifically higher interest rates as well as other impacts of inflation. These macroeconomic conditions are likely to continue for the near term. For information on general economic risk, including interest rate and inflation risk, refer to the Enterprise Risk and Risk Management General Economic Risk section.
FLORIDA ELECTRIC UTILITY
Florida Electric Utility consists of TEC, a vertically integrated regulated electric utility engaged in the generation, transmission and distribution of electricity, serving customers in West Central Florida. TEC has $12 billion USD of assets and approximately 840,000 customers at December 31, 2023. TEC owns 6,433 megawatts (MW) of generating capacity, of which 74 per cent is natural gas fired, 19 per cent is solar and 7 per cent is coal. TEC owns 2,192 kilometres of transmission facilities and 20,299 kilometres of distribution facilities. TEC meets the planning criteria for reserve capacity established by the FPSC, which is a 20 per cent reserve margin over firm peak demand.
TECs 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 10.20 per cent is used for the calculation of the return on investments for clauses.
EMERA 2023 ANNUAL REPORT | 19 |
Managements Discussion & Analysis
TEC anticipates earning towards the lower end of the ROE range in 2024 but expects earnings to be higher than 2023. Normalizing 2023 for weather, TEC sales volumes in 2024 are projected to be higher than 2023 due to customer growth. TEC expects customer growth rates in 2024 to be comparable to 2023, reflective of the expected economic growth in Florida.
On February 1, 2024, TEC notified the FPSC of its intent to seek a base rate increase effective January 2025, reflecting a revenue requirement increase of approximately $290 to $320 million USD and additional adjustments of approximately $100 million USD and $70 million USD for 2026 and 2027, respectively. TECs proposed rates include recovery of solar generation projects, energy storage capacity, a more resilient and modernized energy control center, and numerous other resiliency and reliability projects. The filing range amounts are estimates until TEC files its detailed case in April 2024. The FPSC is scheduled to hear the case in Q3 2024 with a decision expected by the end of 2024.
On August 16, 2023, TEC filed a petition to implement the 2024 Generation Base Rate Adjustment provisions pursuant to the 2021 rate case settlement agreement. Inclusive of TECs ROE adjustment, the increase of $22 million USD was approved by the FPSC on November 17, 2023.
On January 23, 2023, TEC petitioned the FPSC for recovery of the storm reserve regulatory asset and the replenishment of the balance in the storm reserve to the approved storm reserve level of $56 million USD, for a total of $131 million USD. The storm cost recovery surcharge was approved by the FPSC on March 7, 2023, and TEC began applying the surcharge in April 2023. Subsequently, on November 9, 2023, the FPSC approved TECs petition, filed on August 16, 2023, to update the total storm cost collection to $134 million USD. It also changed the collection of the expected remaining balance of $29 million USD as of December 31, 2023, from over the first three months of 2024 to over the 12 months of 2024. The storm recovery is subject to review of the underlying costs for prudency and accuracy by the FPSC and issuance of an order by the FPSC is expected by Q3 2024.
In Q3 2023, TEC was impacted by Hurricane Idalia. The related storm restoration costs were approximately $35 million USD, which were charged to the storm reserve regulatory asset, resulting in minimal impact to earnings. TEC will determine the timing of the request for recovery of Hurricane Idalia costs at a future time.
On January 23, 2023, TEC requested an adjustment to its fuel charges to recover the 2022 fuel under-recovery of $518 million USD over a period of 21 months. The request also included an adjustment to 2023 projected fuel costs to reflect the reduction in natural gas prices since September 2022 for a projected reduction of $170 million USD for the balance of 2023. The changes were approved by the FPSC on March 7, 2023, and were effective beginning on April 1, 2023.
In 2024, capital investment in the Florida Electric Utility segment is expected to be $1.3 billion USD (2023 $1.3 billion USD), including allowance for funds used during construction (AFUDC). Capital projects include solar investments, grid modernization, storm hardening investments and building resilience.
CANADIAN ELECTRIC UTILITIES
Canadian Electric Utilities includes NSPI and ENL. NSPI is a vertically integrated regulated electric utility engaged in the generation, transmission and distribution of electricity and the primary electricity supplier to customers in Nova Scotia. ENL is a holding company with equity investments in NSPML and LIL: two transmission investments related to the development of an 824 MW hydroelectric generating facility at Muskrat Falls on the Lower Churchill River in Labrador.
NSPI
With $7.2 billion of assets and approximately 549,000 customers, NSPI owns 2,422 MW of generating capacity, of which 44 per cent is coal and/or oil-fired; 28 per cent is natural gas and/or oil; 19 per cent is hydro, wind, or solar; 7 per cent is petroleum coke (petcoke) and 2 per cent is biomass-fueled generation. In addition, NSPI has contracts to purchase renewable energy from independent power producers (IPPs) and community feed-in tariff (COMFIT) participants, which own 532 MW of capacity. NSPI also has rights to 153 MW of Maritime Link capacity, representing Nalcor Energys (Nalcor) Nova Scotia Block (NS Block) delivery obligations, as discussed below. NSPI owns approximately 5,000 kilometres of transmission facilities and 28,000 kilometres of distribution facilities.
20 | EMERA 2023 ANNUAL REPORT |
Managements Discussion & Analysis
Nalcor is obligated to provide NSPI with approximately 900 Gigawatt hours (GWh) of energy annually over 35 years. In addition, for the first five years of the NS Block, Nalcor is obligated to provide approximately 240 GWh of additional energy from the Supplemental Energy Block transmitted through the Maritime Link. NSPI has the option of purchasing additional market-priced energy from Nalcor through the Energy Access Agreement. The Energy Access Agreement enables NSPI to access a market- priced bid from Nalcor for up to 1.8 Terawatt hours (TWh) of energy in any given year and, on average, 1.2 TWh of energy per year through August 31, 2041.
NSPIs 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 of approved rate base.
NSPI expects earnings and sales volumes to be higher in 2024 than 2023 but anticipates earning below its allowed ROE range in 2024.
On January 29, 2024, NSPI applied to the UARB for approval of a structure that would begin to recover the outstanding Fuel Adjustment Mechanism (FAM) balance. As part of the application, NSPI requested approval for the sale of $117 million of the FAM regulatory asset to Invest Nova Scotia, a provincial Crown corporation, with the proceeds paid to NSPI upon approval. NSPI has requested approval to collect from customers the amortization and financing costs of $117 million on behalf of Invest Nova Scotia over a 10-year period, and remit those amounts to Invest Nova Scotia as collected, reducing short-term customer rate increases relative to the currently established FAM process. If approved, this portion of the FAM regulatory asset would be removed from the Consolidated Balance Sheets and NSPI would collect the balance on behalf of Invest Nova Scotia in NSPI rates beginning in 2024. A decision is expected in the first half of 2024. It is anticipated that NSPI will apply to the UARB later in 2024 to collect additional under-recovered fuel amounts in 2025 or future periods, subject to the approval of the UARB.
On October 31, 2023, NSPI submitted an application to the UARB to defer $24 million in incremental operating costs incurred during Hurricane Fiona storm restoration efforts in September 2022. NSPI is seeking amortization of the costs over a period to be approved by the UARB during a future rate setting process. At December 31, 2023, the $24 million is deferred to Other long- term assets, pending UARB approval. A decision is expected from the UARB in 2024.
On September 16, 2023, Nova Scotia was struck by post-tropical storm Lee and as a result, approximately 280,000 customers lost power. The total cost of storm restoration was $19 million, with $9 million charged to OM&G, $5 million capitalized to property, plant and equipment (PP&E) and $5 million deferred to the UARB approved storm rider. The storm rider, for each of 2023, 2024, and 2025, allows NSPI to apply to the UARB for deferral and recovery of expenses if major storm restoration expenses exceed approximately $10 million in any given year. The application for deferral of the storm rider is made in the year following the year of the incurred costs, with recovery beginning in the year after the application.
On February 2, 2023, the UARB approved the General Rate Application settlement agreement between NSPI, key customer representatives and participating interest groups. This resulted in average customer rate increases of 6.9 per cent effective on February 2, 2023, and a further average increase of 6.5 per cent on January 1, 2024, with any under or over-recovery of fuel costs addressed through the UARBs established FAM process. It also established a storm rider, described above, and a demand-side management rider. On March 27, 2023, the UARB issued a final order approving the electricity rates effective on February 2, 2023.
In 2024, capital investment, including AFUDC, is expected to be $435 million (2023 $451 million). NSPI is primarily investing in capital projects required to support power system reliability and reliable service for customers.
EMERA 2023 ANNUAL REPORT | 21 |
Managements Discussion & Analysis
Environmental Legislation and Regulations
NSPI is subject to environmental laws and regulations set by both the Government of Canada and the Province of Nova Scotia (the Province). NSPI continues to work with both levels of government to comply with these laws and regulations to maximize efficiency of emission control measures and minimize customer cost. NSPI anticipates that costs prudently incurred to achieve legislated compliance will be recoverable under NSPIs regulatory framework. NSPI faces risks associated with achieving climate- related and environmental legislative requirements, including the risk of non-compliance, which could adversely affect NSPIs operations and financial performance. For further discussion on these risks and environmental legislation and regulations, refer to the Enterprise Risk and Risk Management section. Recent developments related to provincial and federal environmental laws and regulations are outlined below.
Clean Electricity Solutions Task Force:
The Clean Electricity Solutions Task Force (the Task Force) was created by the Province in April 2023 to advise the provincial government on Nova Scotias transition away from coal to more renewable sources of energy. On February 23, 2024, the Task Force released its report and recommendations, based on engagement with stakeholders, including NSPI. The Task Force report focuses on findings related to system operations, regulatory oversight, reliability, transmission and affordability. The Task Force announced a number of recommendations, including a strengthening of the authority and independence of the regulator and the establishment of an independent system operator, in order to support the continuing transition to clean energy and the achievement of federal and provincial clean energy goals and legislation. The Province announced they intend to accept these recommendations and will table enabling legislation in its upcoming session which starts February 27, 2024.
RER:
On April 6, 2023, the Province levied a $10 million penalty on NSPI for non-compliance with the RER compliance period ending in 2022. The penalty was recorded in OM&G on the Consolidated Statements of Income. On May 26, 2023, NSPI initiated an appeal of the penalty through a proceeding with the UARB, as permitted under the RER. On October 12, 2023, the UARB decided that it will hear the appeal by giving due deference to the Provinces decision but permitting the filing of new evidence to support the parties positions. The hearing for the matter is scheduled for June 2024 and a decision is expected before the end of 2024.
Carbon Pricing Regulations:
In November 2022, the Province enacted amendments to the Environment Act which provided the framework for Nova Scotia to implement an output-based pricing system (OBPS) to comply with the Government of Canadas 2023 through 2030 carbon pollution pricing regulations effective January 1, 2023. The Government of Canada approved the Provinces proposed system, however the OBPS will be subject to an interim review by the Government of Canada of the standards effective for 2026. The final Output-Based Pricing System Reporting and Compliance Regulations were prescribed by Order in Council dated January 30, 2024. The OBPS implements greenhouse gas (GHG) emissions performance standards for large industrial GHG emitters that vary by fuel type. GHG emissions in excess of the prescribed intensity standards will be subject to a carbon price that starts at $65 per tonne in 2023 and will increase by $15 per tonne annually, reaching $170 per tonne by 2030. NSPIs regulatory framework provides for the recovery of costs prudently incurred to comply with carbon pricing programs pursuant to NSPIs FAM.
Nova Scotia Cap-and-Trade Program Regulations:
NSPI was a participant in the Nova Scotia Cap-and-Trade Program and was subject to the 2019 through 2022 compliance period. On March 16, 2023, the Province provided NSPI with emissions allowances sufficient to achieve compliance for the 2019 through 2022 compliance period. As such, compliance costs accrued of $166 million were reversed in Q1 2023. The credits NSPI purchased from provincial auctions in the amount of $6 million were not refunded and no further costs were incurred to achieve compliance with the Nova Scotia Cap-and-Trade Program.
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Managements Discussion & Analysis
Other Legislation
Electricity Act Amendment:
On November 9, 2023, the Province enacted amendments in the Electricity Act which permit the Governor in Council to approve energy storage projects proposed by a public utility and owned wholly or in majority by the public utility if the project is in the best interest of ratepayers. Further, the amendments to the Electricity Act expand the ability of the Province to require NSPI to enter into power purchase agreements with renewable generation facilities by further empowering the Province to require NSPI to enter into an agreement for the sale of the electricity to specified customers. This allows specified customers to buy renewable electricity from specified producers, with NSPI managing the transmission and sale of the energy. On December 21, 2023, the Governor in Council enacted regulations which directed NSPI to install three 50 MW four-hour duration grid-scale batteries as part of the regulated assets of NSPI.
Performance Standards Penalty Amendment:
On April 12, 2023, the Province enacted amendments to the Public Utilities Act which increased the cumulative total of administrative penalties that could be levied by the UARB against NSPI for non-compliance with current and future performance standards in a calendar year from $1 million to $25 million. Any administrative penalties levied against NSPI must be credited to customers and NSPI cannot recover administrative penalties imposed through rates.
ENL
Total equity earnings from NSPML and LIL are expected to be higher in 2024, compared to 2023 resulting from an increased investment in LIL planned for 2024. Both the NSPML and LIL investments are recorded as Investments subject to significant influence on Emeras Consolidated Balance Sheets.
NSPML
Equity earnings from the Maritime Link are dependent on the approved ROE and operational performance of NSPML. NSPMLs approved regulated ROE range is 8.75 per cent to 9.25 per cent, based on an actual five-quarter average regulated common equity component of up to 30 per cent.
The Maritime Link assets entered service on January 15, 2018, enabling the transmission of energy between Newfoundland and Nova Scotia, improved reliability and ancillary benefits, supporting the efficiency and reliability of energy in both provinces. Nalcors NS Block delivery obligations commenced on August 15, 2021, and the NS Block will be delivered over the next 35 years pursuant to the project agreements.
On December 21, 2023, NSPML received approval to collect up to $164 million from NSPI for the recovery of costs associated with the Maritime Link in 2024; subject to a holdback of $4 million per month, as discussed below.
On October 4, 2023 and January 31, 2024, the UARB issued decisions providing clarification on remaining aspects of the Maritime Link holdback mechanism primarily relating to release of past and future holdback amounts and requirements to end the holdback mechanism. In these decisions, the UARB agreed with the Companys submission that $12 million ($8 million related to 2022 and $4 million relating to 2023) of the previously recorded holdback remain credited to NSPIs FAM, with the remainder released to NSPML and recorded in Emeras Income from equity investments. NSPML did not record any additional holdback in Q4 2023. The UARB also confirmed that the holdback mechanism will cease once 90 per cent of NS Block deliveries are achieved for 12 consecutive months (subject to potential relief for planned outages or exceptional circumstances) and the net outstanding balance of previously underdelivered NS Block energy is less than 10 per cent of the contracted annual amount. In addition, the UARB increased the monthly holdback amount from $2 million to $4 million beginning December 1, 2023. NSPML expects to file an application to terminate the holdback mechanism in 2024.
NSPML does not anticipate any significant capital investment in 2024.
EMERA 2023 ANNUAL REPORT | 23 |
Managements Discussion & Analysis
LIL
ENL is a limited partner with Nalcor in LIL. Construction of the LIL is complete and the Newfoundland Electrical System Operator confirmed the asset to be operating suitably to support reliable system operation and full functionality at 700MW, which was validated by the Government of Canadas Independent Engineer issuing its Commissioning Certificate on April 13, 2023.
Upon issuance of the Commissioning Certificate, AFUDC equity earnings ceased and cash equity earnings and return of equity to Emera commenced. The first distribution was received from the LIL partnership in Q4 2023.
Equity earnings from the LIL investment are based upon the book value of the equity investment and the approved ROE. Emeras current equity investment is $747 million, comprised of $410 million in equity contribution and $337 million of accumulated equity earnings. Emeras total equity contribution in the LIL, excluding accumulated equity earnings, is estimated to be approximately $650 million once the final costing has been confirmed by Nalcor to determine the amount of the remaining investment.
GAS UTILITIES AND INFRASTRUCTURE
Gas Utilities and Infrastructure includes PGS, NMGC, SeaCoast, Brunswick Pipeline and Emeras equity investment in M&NP. PGS is a regulated gas distribution utility engaged in the purchase, distribution and sale of natural gas serving customers in Florida. NMGC is an intrastate regulated gas distribution utility engaged in the purchase, transmission, distribution and sale of natural gas serving customers in New Mexico. SeaCoast is a regulated intrastate natural gas transmission company offering services in Florida. Brunswick Pipeline is a regulated 145-kilometre pipeline delivering re-gasified liquefied natural gas from Saint John, New Brunswick, to markets in the northeastern United States.
Peoples Gas System
With $2.8 billion USD of assets and approximately 490,000 customers, the PGS system includes 24,300 kilometres of natural gas mains and 13,500 kilometres of service lines. Natural gas throughput (the amount of gas delivered to its customers, including transportation-only service) was 2 billion therms in 2023.
Beginning in 2024, the approved ROE range for PGS is 9.15 per cent to 11.15 per cent (2023 8.9 per cent to 11.0 per cent), based on an allowed equity capital structure of 54.7 per cent (2023 54.7 per cent). An ROE of 10.15 per cent (2023 9.9 per cent) is used for the calculation of return on investments for clauses.
New Mexico Gas Company, Inc.
With $1.8 billion USD of assets and approximately 540,000 customers, NMGCs system includes approximately 2,408 kilometres of transmission pipelines and 17,657 kilometres of distribution pipelines. Annual natural gas throughput was approximately 1 billion therms in 2023.
The approved ROE for NMGC is 9.375 per cent, on an allowed equity capital structure of 52 per cent.
Gas Utilities and Infrastructure Outlook
Gas Utilities and Infrastructure USD earnings are anticipated to be higher in 2024 than 2023, primarily due to a base rate increase effective January 2024 at PGS and an expected base rate increase effective Q4 2024 at NMGC, partially offset by lower asset optimization revenues expected at NMGC.
PGS expects rate base to be higher than in 2023 and anticipates earning within its allowed ROE range in 2024. USD earnings for 2024 are expected to be to be significantly higher than in 2023 primarily due to higher revenue from new base rates in support of significant ongoing system investment and continued customer growth in 2024, which is expected to be consistent with Floridas population growth rates.
On April 4, 2023, PGS filed a rate case with the FPSC and a hearing for the matter was held in September 2023. On November 9, 2023, the FPSC approved a $118 million USD increase to base revenues which includes $11 million USD transferred from the cast iron and bare steel replacement rider, for a net incremental increase to base revenues of $107 million USD. This reflects a 10.15 per cent midpoint ROE with an allowed equity capital structure of 54.7 per cent. A final order was issued on December 27, 2023, with the new rates effective January 2024.
24 | EMERA 2023 ANNUAL REPORT |
Managements Discussion & Analysis
The 2020 PGS rate case settlement provided the ability to reverse a total of $34 million USD of accumulated depreciation through 2023. PGS reversed $20 million USD of accumulated depreciation in 2023 and $14 million USD in 2022.
NMGC expects 2024 rate base growth to be consistent with 2023, with slightly lower USD earnings as a result of lower asset optimization revenues, partially offset by higher revenue from expected new base rates, effective Q4 2024. NMGC anticipates earning near its authorized ROE in 2024. Customer growth rates are expected to be consistent with historical trends.
On September 14, 2023, NMGC filed a rate case with the NMPRC for new base rates to become effective Q4 2024. NMGC requested a $49 million USD increase in annual base revenues primarily as a result of increased operating costs and capital investments in pipeline projects and related infrastructure. The rate case includes a requested ROE of 10.5 per cent. A final order from the NMPRC is expected in Q3 2024.
In 2024, capital investment in the Gas Utilities and Infrastructure segment is expected to be approximately $465 million USD (2023 $495 million USD), including AFUDC. PGS and NMGC will make investments to maintain the reliability of their systems and support customer growth.
OTHER ELECTRIC UTILITIES
Other Electric Utilities includes Emera (Caribbean) Incorporated (ECI), a holding company with regulated electric utilities. ECIs regulated utilities include vertically integrated regulated electric utilities of BLPC on the island of Barbados, GBPC on Grand Bahama Island, and an equity investment in Lucelec on the island of St. Lucia.
BLPC
With $517 million USD of assets and approximately 134,000 customers, BLPC owns 243 MW of generating capacity, of which 96 per cent is oil-fired and four per cent is solar. BLPC owns approximately 188 kilometres of transmission facilities and 3,839 kilometres of distribution facilities. BLPCs approved regulated return on rate base for 2023 was 10 per cent.
GBPC
With $334 million USD of assets and approximately 19,000 customers, GBPC owns 98 MW of oil-fired generation, approximately 90 kilometres of transmission facilities and 994 kilometres of distribution facilities. GBPCs approved regulatory return on rate base for 2024 is 8.52 per cent (2023 8.32 per cent).
Other Electric Utilities Outlook
Other Electric Utilities USD earnings in 2024 are expected to increase over the prior year.
BLPC currently operates pursuant to a single integrated license to generate, transmit and distribute electricity on the island of Barbados until 2028. In 2019, the Government of Barbados passed legislation requiring multiple licenses for the supply of electricity. In 2021, BLPC reached commercial agreement with the Government of Barbados for each of the license types, subject to the passage of implementing legislation. The timing of the final enactment is unknown at this time, but BLPC will work towards the implementation of the licenses once enacted.
In 2021, BLPC submitted a general rate review application to the FTC. In September 2022, the FTC granted BLPC interim rate relief, allowing an increase in base rates of approximately $1 million USD per month. On February 15, 2023, the FTC issued a decision on the application which included the following significant items: an allowed regulatory ROE of 11.75 per cent, an equity capital structure of 55 per cent, a directive to update the major components of rate base to September 16, 2022, and a directive to establish regulatory liabilities related to the self-insurance fund of $50 million USD, prior year benefits recognized on remeasurement of deferred income taxes of $5 million USD, and accumulated depreciation of $16 million USD. On March 7, 2023, BLPC filed a Motion for Review and Variation (the Motion) and applied for a stay of the FTCs decision, which was subsequently granted. On November 20, 2023, the FTC issued their decision dismissing the Motion. Interim rates continue to be in effect through to a date to be determined in a final decision and order.
EMERA 2023 ANNUAL REPORT | 25 |
Managements Discussion & Analysis
On December 1, 2023, BLPC appealed certain aspects of the FTCs February 15 and November 20, 2023, decisions to the Supreme Court of Barbados in the High Court of Justice (the Court) and requested that they be stayed. On December 11, 2023, the Court granted the stay. BLPCs position is that the FTC made errors of law and jurisdiction in their decisions and believes the success of the appeal is probable, and as a result, the adjustments to BLPCs final rates and rate base, including any adjustments to regulatory assets and liabilities, have not been recorded at this time. Management does not expect the final decision and order to have a material impact on adjusted net income.
In 2024, capital investment in the Other Electric Utilities segment is expected to be approximately $80 million USD (2023 $47 million USD), primarily in more efficient and cleaner sources of generation, including renewables and battery storage.
OTHER
The Other segment includes those business operations that in a normal year are below the required threshold for reporting as separate segments; and corporate expense and revenue items that are not directly allocated to the operations of Emeras subsidiaries and investments.
Business operations in the Other segment include Emera Energy and Block Energy LLC (Block Energy). Emera Energy consists of EES, a wholly owned physical energy marketing and trading business and an equity investment in a 50 per cent joint venture ownership of Bear Swamp, a 660 MW pumped storage hydroelectric facility in northwestern Massachusetts. Block Energy is a wholly owned technology company focused on finding ways to deliver renewable and resilient energy to customers.
Corporate items included in the Other segment are certain corporate-wide functions including executive management, strategic planning, treasury services, legal, financial reporting, tax planning, corporate business development, corporate governance, investor relations, risk management, insurance, acquisition and disposition related costs, gains or losses on select assets sales, and corporate human resource activities. It includes interest revenue on intercompany financings and interest expense on corporate debt in both Canada and the United States. It also includes costs associated with corporate activities that are not directly allocated to the operations of Emeras subsidiaries and investments.
Earnings from EES are generally dependent on market conditions. In particular, volatility in natural gas and electricity markets, which can be influenced by weather, local supply constraints and other supply and demand factors, can provide higher levels of margin opportunity. The business is seasonal, with Q1 and Q4 usually providing the greatest opportunity for earnings. EES is generally expected to deliver annual adjusted net income within its guidance range of $15 to $30 million USD.
The adjusted net loss from the Other segment is expected to be higher in 2024 due to increased interest expense and lower contribution to net income from Emera Energy primarily as a result of one-time investment tax credits at Bear Swamp in 2023.
The Other segment does not anticipate any significant capital investment in 2024.
26 | EMERA 2023 ANNUAL REPORT |
Managements Discussion & Analysis
Consolidated Balance Sheet Highlights
Significant changes in the Consolidated Balance Sheets between December 31, 2022 and December 31, 2023 include:
millions of dollars |
Increase (Decrease) |
Explanation | ||||||
Assets | ||||||||
Cash and cash equivalents | $ | 257 | Increased due to cash from operations, proceeds from long-term debt issuances at PGS and NSPI, and issuance of Emera common stock. These were partially offset by investment in PP&E at the regulated utilities, net repayments of debt at TEC, and dividends paid on Emera common stock | |||||
Derivative instruments (current and long-term) | (156 | ) | Decreased due to settlements of derivative instruments and decreased pricing on power derivative instruments at NSPI, partially offset by reversal of 2022 contracts at EES | |||||
Regulatory assets (current and long-term) | (515 | ) | Decreased due to higher fuel clause and storm cost recoveries at TEC, and reversal of accrued Cap-and-Trade emission compliance charges at NSPI. These were partially offset by increased FAM deferrals at NSPI due to an under-recovery of fuel costs and a change in fuel cost recovery methodology for an industrial customer, and increased deferred income tax regulatory assets at NSPI | |||||
Receivables and other assets (current and long-term) | (1,079 | ) | Decreased due to lower gas transportation assets, decreased cash collateral and lower trade receivables as a result of lower commodity prices at EES, and settlement of the gas hedge receivable at NMGC | |||||
PP&E, net of accumulated depreciation and amortization | 1,380 | Increased due to capital additions in excess of depreciation and amortization, partially offset by the effect of FX translation of Emeras non-Canadian affiliates | ||||||
Goodwill | (141 | ) | Decreased due to the effect of the FX translation of non-Canadian affiliates | |||||
Liabilities and Equity | ||||||||
Short-term debt and long-term debt (including current portion) | $ | 754 | Issuance of long-term debt at PGS and NSPI and proceeds from committed credit facilities at Emera, partially offset by net repayments under committed credit facilities at NSPI and TEC, repayment of debt at NMGC, and the effect of the FX translation of non-Canadian affiliates | |||||
Accounts payable | (571 | ) | Decreased due to lower commodity prices at EES, NMGC and TEC, decreased cash collateral position on derivative instruments and lower fuel related payables at NSPI | |||||
Deferred income tax liabilities, net of deferred income tax assets | 185 | Increased due to tax deductions in excess of accounting depreciation related to PP&E, partially offset by changes in derivative instruments and increased tax credits related to solar projects at TEC and Bear Swamp facility upgrades | ||||||
Derivative instruments (current and long-term) |
(574 | ) | Decreased due to changes in existing positions and reversal of 2022 contracts, partially offset by new contracts in 2023 at EES | |||||
Regulatory liabilities (current and long-term) |
(501 | ) | Decreased due to lower deferrals related to derivative instruments at NSPI and settlement of NMGC gas hedges | |||||
Other liabilities (current and long-term) |
(157 | ) | Decreased due to reversal of accrued Cap-and-Trade emissions compliance charges at NSPI | |||||
Common stock | 700 | Increased due to shares issued | ||||||
Accumulated other comprehensive income |
(273 | ) | Decreased due to the effect of the FX translation of non-Canadian affiliates | |||||
Retained earnings | 219 | Increased due to net income in excess of dividends paid |
EMERA 2023 ANNUAL REPORT | 27 |
Managements Discussion & Analysis
Other Developments
Increase in Common Dividends
On September 20, 2023, the Emera Board of Directors (the Board) approved an increase in the annual common share dividend rate to $2.87 from $2.76 per common share. The first payment was effective November 15, 2023. Emera also extended its dividend growth rate target of four to five per cent through 2026.
Financial Highlights
FLORIDA ELECTRIC UTILITY
For the | Three months ended December 31 |
Year ended December 31 |
||||||||||||||
millions of USD (except as indicated) |
2023 | 2022 | 2023 | 2022 | ||||||||||||
Operating revenues regulated electric |
$ | 613 | $ | 597 | $ | 2,637 | $ | 2,523 | ||||||||
Regulated fuel for generation and purchased power |
$ | 162 | $ | 201 | $ | 682 | $ | 832 | ||||||||
Contribution to consolidated net income |
$ | 85 | $ | 91 | $ | 466 | $ | 458 | ||||||||
Contribution to consolidated net income CAD |
$ | 115 | $ | 124 | $ | 627 | $ | 596 | ||||||||
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Average fuel costs in dollars per MWh |
$ | 34 | $ | 41 | $ | 31 | $ | 39 | ||||||||
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The impact of the change in the FX rate increased CAD earnings for the three months and year ended December 31, 2023, by $1 million and $22 million, respectively.
Net Income
Highlights of the net income changes are summarized in the following table:
For the millions of USD |
Three months ended December 31 |
Year ended December 31 |
||||||
Contribution to consolidated net income 2022 |
$ | 91 | $ | 458 | ||||
Increased operating revenues due to storm cost recovery surcharge revenue (offset in OM&G), new base rates and customer growth driving higher sales volumes, partially offset by changes in fuel recovery clause revenue and unfavourable weather |
16 | 114 | ||||||
Decreased fuel for generation and purchased power due to lower natural gas prices |
39 | 150 | ||||||
Increased OM&G primarily due to storm cost recovery recognition related to the storm surcharge (offset in revenue) and timing of deferred clause recoveries |
(25 | ) | (136 | ) | ||||
Increased depreciation and amortization due to additions to facilities and generation projects placed in service |
(8 | ) | (33 | ) | ||||
Increased interest expense due to higher interest rates and higher borrowings to support capital investments and ongoing operations |
(7 | ) | (59 | ) | ||||
Increased state, and municipal taxes due to higher retail sales and higher taxable property placed in service |
(8 | ) | (33 | ) | ||||
(Increased) decreased income tax expense primarily due to production tax credits related to solar facilities |
(6 | ) | 7 | |||||
Other |
(7 | ) | (2 | ) | ||||
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Contribution to consolidated net income 2023 |
$ | 85 | $ | 466 | ||||
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28 | EMERA 2023 ANNUAL REPORT |
Managements Discussion & Analysis
Operating Revenues Regulated Electric
Annual electric revenues and sales volumes are summarized in the following table by customer class:
Electric Revenues (millions of USD) |
Electric Sales Volumes (Gigawatt hours (GWh)) |
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2023 | 2022 | 2023 | 2022 | |||||||||||||
Residential |
$ | 1,711 | $ | 1,381 | 10,307 | 10,109 | ||||||||||
Commercial |
803 | 666 | 6,462 | 6,300 | ||||||||||||
Industrial |
203 | 176 | 2,082 | 2,111 | ||||||||||||
Other (1) |
(80 | ) | 300 | 2,194 | 2,352 | |||||||||||
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|||||||||
Total |
$ | 2,637 | $ | 2,523 | 21,045 | 20,872 | ||||||||||
|
|
|
|
|
|
|
|
(1) | Other includes regulatory deferrals related to clauses, sales to public authorities, off-system sales to other utilities. |
Regulated Fuel for Generation and Purchased Power
Annual production volumes are summarized in the following table:
Production Volumes (GWh) | ||||||||
2023 | 2022 | |||||||
Natural gas |
17,843 | 17,083 | ||||||
Solar |
1,748 | 1,492 | ||||||
Purchased power |
1,443 | 1,685 | ||||||
Coal |
744 | 1,325 | ||||||
|
|
|
|
|||||
Total |
21,778 | 21,585 | ||||||
|
|
|
|
TECs fuel costs are affected by commodity prices and generation mix that is largely dependent on economic dispatch of the generating fleet, bringing the lowest cost options on first (renewable energy from solar or battery storage), 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.
Regulatory Environment
TEC is regulated by the FPSC and is also subject to regulation by the FERC. The FPSC sets rates at a level that allows utilities such as TEC to collect total revenues or revenue requirements equal to their cost of providing service, plus an appropriate return on invested capital. Base rates are determined in FPSC rate setting hearings which can occur at the initiative of TEC, the FPSC
or other interested parties. For further details on TECs regulatory environment, base rates and recovery mechanisms, refer to note 6 in the consolidated financial statements.
CANADIAN ELECTRIC UTILITIES
For the | Three months ended December 31 |
Year ended December 31 |
||||||||||||||
millions of dollars (except as indicated) |
2023 | 2022 | 2023 | 2022 | ||||||||||||
Operating revenues regulated electric |
$ | 439 | $ | 421 | $ | 1,671 | $ | 1,675 | ||||||||
Regulated fuel for generation and purchased power (1) |
$ | 234 | $ | 173 | $ | 777 | $ | 950 | ||||||||
Contribution to consolidated adjusted net income |
$ | 68 | $ | 46 | $ | 247 | $ | 222 | ||||||||
NSPML unrecoverable costs |
$ | | $ | | $ | | $ | (7 | ) | |||||||
Contribution to consolidated net income |
$ | 68 | $ | 46 | $ | 247 | $ | 215 | ||||||||
|
|
|
|
|
|
|
|
|||||||||
Average fuel costs in dollars per MWh (2) |
$ | 81 | $ | 61 | $ | 70 | $ | 85 | ||||||||
|
|
|
|
|
|
|
|
(1) | Regulated fuel for generation and purchased power includes NSPIs FAM deferral on the Consolidated Statements of Income, however, it is excluded in the segment overview. |
(2) | Average fuel costs for the year ended December 31, 2023 include reversal of the $166 million of the Nova Scotia Cap-and-Trade Program provision (2022 $134 million expense). |
EMERA 2023 ANNUAL REPORT | 29 |
Managements Discussion & Analysis
Canadian Electric Utilities contribution to consolidated adjusted net income is summarized in the following table:
For the | Three months ended December 31 |
Year ended December 31 |
||||||||||||||
millions of dollars |
2023 | 2022 | 2023 | 2022 | ||||||||||||
NSPI |
$ | 40 | $ | 23 | $ | 141 | $ | 131 | ||||||||
Equity investment in LIL |
16 | 15 | 60 | 55 | ||||||||||||
Equity investment in NSPML (1) |
12 | 8 | 46 | 36 | ||||||||||||
|
|
|
|
|
|
|
|
|||||||||
Contribution to consolidated adjusted net income |
$ | 68 | $ | 46 | $ | 247 | $ | 222 | ||||||||
|
|
|
|
|
|
|
|
(1) | Excludes $7 million in NSPML unrecoverable costs, after-tax, for the year ended December 31, 2022. |
Net Income
Highlights of the net income changes are summarized in the following table:
For the millions of dollars |
Three months ended December 31 |
Year ended December 31 |
||||||
Contribution to consolidated net income 2022 |
$ | 46 | $ | 215 | ||||
Increased operating revenues quarter-over-quarter due to new rates, increased residential, commercial and other class sales volumes, and favourable weather, partially offset by decreased industrial sales volume. Year-over-year decrease primarily due to changes in fuel cost recovery methodology for an industrial customer (1), partially offset by quarter-over-quarter impacts noted above |
18 | (4 | ) | |||||
Increased fuel for generation and purchased power quarter-over-quarter due to increased commodity prices and partial reversal of Nova Scotia Cap-and-Trade Program costs accrued in 2022, partially offset by a change in generation mix. Year-over-year decreased due to reversal of the Nova Scotia Cap-and-Trade Program provision in 2023, compared to an expense in 2022, partially offset by increased commodity prices and the Nova Scotia OBPS carbon tax accrual |
(61 | ) | 173 | |||||
Increased FAM deferral quarter-over-quarter due to under-recovery of fuel costs. Year-over-year decreased due to reversal of the Nova Scotia Cap-and-Trade provision in 2023, partially offset by increased under-recovery of fuel costs and changes in the fuel recovery methodology for an industrial customer (1) |
74 | (69 | ) | |||||
Increased OM&G due to higher costs for power generation and transmission and distribution field services. Year-over-year also increased due to the recognition of the RER penalty and higher vegetation management costs |
(8 | ) | (46 | ) | ||||
Increased depreciation and amortization due to increased PP&E in service |
(3 | ) | (17 | ) | ||||
Increased interest expense due to increased interest rates and higher debt levels |
(5 | ) | (34 | ) | ||||
Increased income from equity investments at NSPML quarter-over-quarter primarily due to the holdback recognized in Q4 2022. Year-over-year also increased due to partial reversal in Q3 2023 of the holdback recognized in 2022, and higher equity earnings from LIL |
5 | 15 | ||||||
NSPML unrecoverable costs in 2022 |
| 7 | ||||||
Other |
2 | 7 | ||||||
|
|
|
|
|||||
Contribution to consolidated net income 2023 |
$ | 68 | $ | 247 | ||||
|
|
|
|
(1) | For more information on the changes in fuel cost recovery methodology for an industrial customer, refer to note 6 in the 2023 consolidated financial statements |
30 | EMERA 2023 ANNUAL REPORT |
Managements Discussion & Analysis
NSPI
Operating Revenues Regulated Electric
Annual electric revenues and sales volumes are summarized in the following tables by customer class:
Electric Revenues (millions of dollars) |
Electric Sales Volumes (GWh) |
|||||||||||||||
2023 | 2022 | 2023 | 2022 | |||||||||||||
Residential |
$ | 910 | $ | 834 | 4,986 | 4,822 | ||||||||||
Commercial |
463 | 427 | 3,053 | 3,006 | ||||||||||||
Industrial |
219 | 353 | 2,164 | 2,480 | ||||||||||||
Other |
41 | 28 | 239 | 148 | ||||||||||||
|
|
|
|
|
|
|
|
|||||||||
Total |
$ | 1,633 | $ | 1,642 | 10,442 | 10,456 | ||||||||||
|
|
|
|
|
|
|
|
Regulated Fuel for Generation and Purchased Power
Annual production volumes are summarized in the following table:
Production Volumes (GWh) |
||||||||
2023 | 2022 | |||||||
Coal |
3,086 | 3,771 | ||||||
Natural gas |
1,946 | 1,650 | ||||||
Purchased power |
881 | 910 | ||||||
Petcoke |
553 | 897 | ||||||
Oil |
145 | 251 | ||||||
|
|
|
|
|||||
Total non-renewables |
6,611 | 7,479 | ||||||
|
|
|
|
|||||
Purchased power IPP, COMFIT and imports |
3,251 | 2,423 | ||||||
Wind, hydro and solar |
1,149 | 1,105 | ||||||
Biomass |
128 | 127 | ||||||
|
|
|
|
|||||
Total renewables |
4,528 | 3,655 | ||||||
|
|
|
|
|||||
Total production volumes |
11,139 | 11,134 | ||||||
|
|
|
|
NSPIs fuel costs are affected by commodity prices and generation mix, which is largely dependent on economic dispatch of the generating fleet. NSPI brings the lowest cost options on stream first after renewable energy from IPPs including COMFIT participants, for which NSPI has power purchase agreements in place, and the NS Block of energy, including the Supplemental Energy Block, which carries no additional fuel cost outside of the UARB approved annual assessments paid to NSPML for the use of the Maritime Link.
Generation mix may also be affected by plant outages, carbon pricing programs, including the Nova Scotia OBPS, availability of renewable generation, availability of energy from the NS Block, plant performance, and compliance with environmental regulations.
The Nova Scotia Cap-and-Trade Program provision related to the accrued cost of acquiring emissions credits for the 2019 through 2022 compliance period. As of December 31, 2022, NSPI had recognized a cumulative $166 million accrual in fuel costs related to anticipated purchase of emissions credits and $6 million related to credits purchased from provincial auction. Accrued compliance costs of $166 million were reversed in Q1 2023 and NSPI does not anticipate further costs related to the Nova Scotia Cap-and-Trade Program. For further information on the reversal of this non-cash accrual and the FAM regulatory balance, refer to the Business Overview and Outlook Canadian Electric Utilities NSPI section and note 6 in the consolidated financial statements.
Regulatory Environment NSPI
NSPI is a public utility as defined in 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 NSPIs operations and expenditures. Electricity rates for NSPIs 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 NSPIs or the UARBs request. For further details on NSPIs regulatory environment and recovery mechanisms, refer to note 6 in the consolidated financial statements.
EMERA 2023 ANNUAL REPORT | 31 |
Managements Discussion & Analysis
GAS UTILITIES AND INFRASTRUCTURE
For the | Three months ended December 31 |
Year ended December 31 |
||||||||||||||
millions of USD (except as indicated) |
2023 | 2022 | 2023 | 2022 | ||||||||||||
Operating revenues regulated gas (1) |
$ | 290 | $ | 372 | $ | 1,114 | $ | 1,296 | ||||||||
Operating revenues non-regulated |
3 | 2 | 15 | 12 | ||||||||||||
Total operating revenue |
$ | 293 | $ | 374 | $ | 1,129 | $ | 1,308 | ||||||||
Regulated cost of natural gas |
$ | 99 | $ | 181 | $ | 391 | $ | 614 | ||||||||
Contribution to consolidated net income |
$ | 43 | $ | 53 | $ | 158 | $ | 170 | ||||||||
|
|
|
|
|
|
|
|
|||||||||
Contribution to consolidated net income CAD |
$ | 59 | $ | 72 | $ | 214 | $ | 221 | ||||||||
|
|
|
|
|
|
|
|
(1) | Operating revenues regulated gas includes $11 million of finance income from Brunswick Pipeline (2022 $13 million) for the three months ended December 31, 2023 and $46 million (2022 $47 million) for the year ended December 31 2023; however, it is excluded from the gas revenues and cost of natural gas analysis below. |
Gas Utilities and Infrastructures contribution to consolidated net income is summarized in the following table:
For the | Three months ended December 31 |
Year ended December 31 |
||||||||||||||
millions of USD |
2023 | 2022 | 2023 | 2022 | ||||||||||||
PGS |
$ | 21 | $ | 17 | $ | 79 | $ | 82 | ||||||||
NMGC |
14 | 22 | 43 | 35 | ||||||||||||
Other |
8 | 14 | 36 | 53 | ||||||||||||
|
|
|
|
|
|
|
|
|||||||||
Contribution to consolidated net income |
$ | 43 | $ | 53 | $ | 158 | $ | 170 | ||||||||
|
|
|
|
|
|
|
|
Impact of the change in the FX rate on CAD earnings was minimal for the three months ended and increased CAD earnings for the year ended December 31, 2023, by $8 million.
Net Income
Highlights of the net income changes are summarized in the following table:
For the millions of USD |
Three months ended December 31 |
Year ended December 31 |
||||||
Contribution to consolidated net income 2022 |
$ | 53 | $ | 170 | ||||
Decreased operating revenues due to lower fuel revenues at PGS and NMGC, and lower off- system sales at PGS, partially offset by new base rates at NMGC and customer growth at PGS |
(71 | ) | (181 | ) | ||||
Decreased asset optimization revenue quarter-over-quarter at NMGC |
(10 | ) | 2 | |||||
Decreased cost of natural gas sold due to lower natural gas prices at PGS and NMGC |
82 | 223 | ||||||
Increased OM&G primarily due to higher labour and benefit costs |
(10 | ) | (20 | ) | ||||
Decreased depreciation and amortization expense quarter-over-quarter due to a higher reversal of accumulated depreciation in 2023 as a result of the 2021 rate case settlement at PGS. Year- over-year increase due to asset growth at PGS and NMGC, partially offset by a higher reversal of accumulated depreciation in 2023 at PGS |
6 | (3 | ) | |||||
Increased interest expense due to higher interest rates and increased borrowings to support ongoing operations and capital investments |
(10 | ) | (33 | ) | ||||
Other |
3 | | ||||||
|
|
|
|
|||||
Contribution to consolidated net income 2023 |
$ | 43 | $ | 158 | ||||
|
|
|
|
32 | EMERA 2023 ANNUAL REPORT |
Managements Discussion & Analysis
Operating Revenues Regulated Gas
Annual gas revenues and sales volumes are summarized in the following tables by customer class:
Gas Revenues (millions of USD) |
Gas Volumes (Therms) |
|||||||||||||||
2023 | 2022 | 2023 | 2022 | |||||||||||||
Residential |
$ | 537 | $ | 614 | 414 | 421 | ||||||||||
Commercial |
315 | 354 | 839 | 836 | ||||||||||||
Industrial (1) |
69 | 64 | 1,615 | 1,429 | ||||||||||||
Other (2) |
147 | 217 | 266 | 227 | ||||||||||||
|
|
|
|
|
|
|
|
|||||||||
Total (3) |
$ | 1,068 | $ | 1,249 | 3,134 | 2,913 | ||||||||||
|
|
|
|
|
|
|
|
(1) | Industrial gas revenue includes sales to power generation customers. |
(2) | Other gas revenue includes off-system sales to other utilities and various other items. |
(3) | Total gas revenue excludes $46 million of finance income from Brunswick Pipeline (2022 $47 million). |
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 interstate pipelines on which PGS has firm transportation capacity for delivery by PGS to its customers. NMGCs natural gas is transported on major interstate pipelines and NMGCs intrastate transmission and distribution system for delivery to customers.
In Florida, natural gas service is unbundled for non-residential customers and residential customers who use more than 1,999 therms annually and elect the option. In New Mexico, NMGC is required, if requested, to provide transportation-only services for all customer classes. The commodity portion of bundled sales is included in operating revenues, at the cost of the gas on a pass-through basis, therefore no net earnings effect when a customer shifts to transportation-only sales.
Annual gas sales by type are summarized in the following table:
Gas Volumes by Type (millions of Therms) |
||||||||
2023 | 2022 | |||||||
Transportation |
2,461 | 2,206 | ||||||
System supply |
673 | 707 | ||||||
|
|
|
|
|||||
Total |
3,134 | 2,913 | ||||||
|
|
|
|
Regulatory Environments
PGS is regulated by the FPSC. The FPSC sets rates at a level that allows utilities such as PGS to collect total revenues or revenue requirements equal to their cost of providing service, plus an appropriate return on invested capital.
NMGC is subject to regulation by the NMPRC. The NMPRC sets rates at a level that allows NMGC to collect total revenues equal to its cost of providing service, plus an appropriate return on invested capital.
For further information on PGS and NMGCs regulatory environment and recovery mechanisms, refer to note 6 in the consolidated financial statements.
EMERA 2023 ANNUAL REPORT | 33 |
Managements Discussion & Analysis
OTHER ELECTRIC UTILITIES
For the | Three months ended December 31 |
Year ended December 31 |
||||||||||||||
millions of USD (except as indicated) |
2023 | 2022 | 2023 | 2022 | ||||||||||||
Operating revenues regulated electric |
$ | 104 | $ | 98 | $ | 390 | $ | 398 | ||||||||
Regulated fuel for generation and purchased power |
$ | 57 | $ | 54 | $ | 204 | $ | 223 | ||||||||
Contribution to consolidated adjusted net income |
$ | 3 | $ | 7 | $ | 26 | $ | 23 | ||||||||
Contribution to consolidated adjusted net income CAD |
$ | 4 | $ | 8 | $ | 35 | $ | 29 | ||||||||
GBPC Impairment charge |
$ | | $ | 54 | $ | | $ | 54 | ||||||||
Equity securities MTM gain (loss) |
$ | 2 | $ | 1 | $ | 2 | $ | (4 | ) | |||||||
Contribution to consolidated net income (loss) |
$ | 5 | $ | (46 | ) | $ | 28 | $ | (35 | ) | ||||||
Contribution to consolidated net income (loss) CAD |
$ | 6 | $ | (62 | ) | $ | 37 | $ | (48 | ) | ||||||
Electric sales volumes (GWh) |
323 | 301 | 1,260 | 1,239 | ||||||||||||
Electric production volumes (GWh) |
345 | 325 | 1,362 | 1,340 | ||||||||||||
|
|
|
|
|
|
|
|
|||||||||
Average fuel cost in dollars per MWh |
$ | 165 | $ | 161 | $ | 150 | $ | 166 | ||||||||
|
|
|
|
|
|
|
|
On March 31, 2022, Emera completed the sale of its 51.9 per cent interest in Dominica Electricity Services Ltd. (Domlec) for proceeds which approximated carrying value. The sale did not have a material impact on earnings.
The impact of the change in the FX rate on CAD earnings for the three months and year ended December 31, 2023 was minimal. Other Electric Utilities contribution to consolidated adjusted net income is summarized in the following table:
For the | Three months ended December 31 |
Year ended December 31 |
||||||||||||||
millions of USD |
2023 | 2022 | 2023 | 2022 | ||||||||||||
BLPC |
$ | 4 | $ | 5 | $ | 18 | $ | 11 | ||||||||
GBPC |
| 1 | 11 | 10 | ||||||||||||
Other |
(1 | ) | 1 | (3 | ) | 2 | ||||||||||
|
|
|
|
|
|
|
|
|||||||||
Contribution to consolidated adjusted net income |
$ | 3 | $ | 7 | $ | 26 | $ | 23 | ||||||||
|
|
|
|
|
|
|
|
Net Income
Highlights of the net income changes are summarized in the following table:
For the millions of USD |
Three months ended December 31 |
Year ended December 31 |
||||||
Contribution to consolidated net income 2022 |
$ | (46 | ) | $ | (35 | ) | ||
Increased operating revenues quarter-over-quarter due to higher fuel revenue at BLPC and GBPC as a result of higher fuel prices and higher sales volumes at BLPC. Year-over-year decreased due to lower fuel revenue at BLPC reflecting lower fuel prices, and the sale of Domlec in Q1 2022, partially offset by interim rates at BLPC and increased sales volumes at BLPC and GBPC |
6 | (8 | ) | |||||
Increased fuel for generation and purchased power quarter-over-quarter due to higher fuel costs at BLPC and GBPC. Decreased year-over-year due to lower fuel prices and change in generation mix at BLPC |
(3 | ) | 19 | |||||
GBPC impairment charge in 2022 |
54 | 54 | ||||||
Other |
(6 | ) | (2 | ) | ||||
|
|
|
|
|||||
Contribution to consolidated net income 2023 |
$ | 5 | $ | 28 | ||||
|
|
|
|
34 | EMERA 2023 ANNUAL REPORT |
Managements Discussion & Analysis
Regulatory Environments
BLPC is regulated by the FTC. Rates are set to recover prudently incurred costs of providing electricity service to customers plus an appropriate return on capital invested.
GBPC is regulated by the GBPA. Rates are set to recover prudently incurred costs of providing electricity service to customers plus an appropriate return on rate base.
For further details on BLPC and GBPCs regulatory environments and recovery mechanisms, refer to note 6 in the consolidated financial statements.
OTHER
For the | Three months ended December 31 |
Year ended December 31 |
||||||||||||||
millions of dollars |
2023 | 2022 | 2023 | 2022 | ||||||||||||
Marketing and trading margin (1) (2) |
$ | 35 | $ | 72 | $ | 96 | $ | 143 | ||||||||
Other non-regulated operating revenue |
5 | 3 | 27 | 16 | ||||||||||||
Total operating revenues non-regulated |
$ | 40 | $ | 75 | $ | 123 | $ | 159 | ||||||||
Contribution to consolidated adjusted net income (loss) |
$ | (71 | ) | $ | (1 | ) | $ | (314 | ) | $ | (218 | ) | ||||
MTM gain, after-tax (3) |
112 | 304 | 167 | 179 | ||||||||||||
|
|
|
|
|
|
|
|
|||||||||
Contribution to consolidated net income (loss) |
$ | 41 | $ | 303 | $ | (147 | ) | $ | (39 | ) | ||||||
|
|
|
|
|
|
|
|
(1) | Marketing and trading margin represents EESs purchases and sales of natural gas and electricity, pipeline and storage capacity costs and energy asset management services revenues. |
(2) | Marketing and trading margin excludes a MTM gain, pre-tax of $131 million in Q4 2023 (2022 $430 million gain) and a gain of $216 million for the year ended December 31, 2023 (2022 $281 million gain). |
(3) | Net of income tax expense of $44 million for the three months ended December 31, 2023 (2022 $124 million expense) and $68 million expense for the year ended December 31, 2023 (2022 $73 million expense). |
Others contribution to consolidated adjusted net income is summarized in the following table:
For the | Three months ended December 31 |
Year ended December 31 |
||||||||||||||
millions of dollars |
2023 | 2022 | 2023 | 2022 | ||||||||||||
Emera Energy |
||||||||||||||||
EES |
$ | 19 | $ | 40 | $ | 46 | $ | 68 | ||||||||
Other |
6 | 1 | 18 | 2 | ||||||||||||
Corporate see breakdown of adjusted contribution below |
(91 | ) | (37 | ) | (356 | ) | (267 | ) | ||||||||
Block Energy LLC (1) |
(4 | ) | (5 | ) | (18 | ) | (18 | ) | ||||||||
Other |
(1 | ) | | (4 | ) | (3 | ) | |||||||||
|
|
|
|
|
|
|
|
|||||||||
Contribution to consolidated adjusted net income (loss) |
$ | (71 | ) | $ | (1 | ) | $ | (314 | ) | $ | (218 | ) | ||||
|
|
|
|
|
|
|
|
(1) | Previously Emera Technologies LLC |
EMERA 2023 ANNUAL REPORT | 35 |
Managements Discussion & Analysis
Net Income
Highlights of the net income changes are summarized in the following table:
For the millions of dollars |
Three months ended December 31 |
Year ended December 31 |
||||||
Contribution to consolidated net income (loss) 2022 |
$ | 303 | $ | (39 | ) | |||
Decreased marketing and trading margin quarter-over-quarter primarily due to weather driven market conditions in Q4 2022 that increased pricing and volatility. Year-over-year decrease reflects less favourable market conditions, specifically lower natural gas prices and volatility and higher cost commitments for gas transportation in 2023 compared to 2022 |
(37 | ) | (47 | ) | ||||
Decreased OM&G, pre-tax, primarily due to the timing of long-term compensation and related hedges |
12 | 10 | ||||||
Increased interest expense, pre-tax, due to increased interest rates and increased total debt |
(8 | ) | (51 | ) | ||||
Increased income tax recovery primarily due to increased losses before provision for income taxes and the recognition of investment tax credits related to Bear Swamp facility upgrades, partially offset by the impact of effective state tax rates |
7 | 26 | ||||||
TGH award in 2022, after tax and legal costs |
(45 | ) | (45 | ) | ||||
Decreased MTM gain, after-tax, quarter-over-quarter due to unfavourable changes in existing positions, partially offset by higher amortization of gas transportation assets in 2022 at EES. Decreased MTM gain after-tax, year-over-year primarily due to higher amortization of gas transportation assets partially offset by favourable changes in existing positions at EES and gains on Corporate FX hedges |
(194 | ) | (12 | ) | ||||
Other |
3 | 11 | ||||||
|
|
|
|
|||||
Contribution to consolidated net income (loss) 2023 |
$ | 41 | $ | (147 | ) | |||
|
|
|
|
Emera Energy
EES derives revenue and earnings from wholesale marketing and trading of natural gas and electricity within the Companys risk tolerances, including those related to value-at-risk (VaR) and credit exposure. EES purchases and sells physical natural gas and electricity, the related transportation and transmission capacity rights, and provides energy asset management services. The primary market area for the natural gas and power marketing and trading business is northeastern North America, including the Marcellus and Utica shale supply areas. EES also participates in the Florida, United States 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 regions 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.
EES contribution to consolidated adjusted net income was $19 million in Q4 2023, compared to $40 million in Q4 2022; and $46 million ($33 million USD) for the year ended December 31, 2023, compared to $68 million ($50 million USD) for the same period in 2022. The 2023 and 2022 EES contribution to consolidated adjusted net income was above the expected EES annual adjusted net income guidance range of $15 to $30 million USD. Market conditions in 2022 were very favourable, due to high natural gas pricing and volatility, which reflected weather patterns and geopolitical conditions.
MTM Adjustments
Emera Energys Marketing and trading margin, 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 table below.
36 | EMERA 2023 ANNUAL REPORT |
Managements Discussion & Analysis
Emera Energy has a number of asset management agreements (AMA) with counterparties, including local gas distribution utilities, power utilities and natural gas producers in North America. The AMAs involve Emera Energy buying or selling gas for a specific term, and the corresponding release of the counterparties gas transportation/storage capacity to Emera Energy. MTM adjustments on these AMAs arise on the price differential between the point where gas is sourced and where it is delivered. At inception, the MTM adjustment is offset fully by the value of the corresponding gas transportation asset, which is amortized over the term of the AMA contract.
Subsequent changes in gas price differentials, to the extent they are not offset by the accounting amortization of the gas transportation asset, will result in MTM gains or losses recorded in income. MTM adjustments may be substantial during the term of the contract, especially in the winter months of a contract when delivered volumes and market pricing are usually at peak levels. As a contract is realized, and volumes reduce, MTM volatility is expected to decrease. Ultimately, the gas transportation asset and the MTM adjustment reduce to zero at the end of the contract term. As the business grows, and AMA volumes increase, MTM volatility resulting in gains and losses may also increase.
Emera Corporate has FX forwards to manage the cash flow risk of forecasted USD cash inflows. Fluctuations in the FX rate result in MTM gains or losses are recorded in Other income, net on the Consolidated Statements of Income.
Corporate
Corporates adjusted loss is summarized in the following table:
For the | Three months ended December 31 |
Year ended December 31 |
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millions of dollars |
2023 | 2022 | 2023 | 2022 | ||||||||||||
Operating expenses (1) |
$ | 7 | $ | 20 | $ | 73 | $ | 83 | ||||||||
Interest expense |
88 | 79 | 329 | 278 | ||||||||||||
Income tax recovery |
(25 | ) | (35 | ) | (111 | ) | (109 | ) | ||||||||
Preferred dividends |
18 | 16 | 66 | 63 | ||||||||||||
TGH award, after tax and legal costs |
| (45 | ) | | (45 | ) | ||||||||||
Other ( 2) (3) |
3 | 2 | (1 | ) | (3 | ) | ||||||||||
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Corporate adjusted net loss (4) |
$ | (91 | ) | $ | (37 | ) | $ | (356 | ) | $ | (267 | ) | ||||
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(1) | Operating expenses include OM&G and depreciation. |
(2) | Other includes realized FX gains and losses on FX hedges entered into to hedge USD denominated operating unit earnings exposure. |
(3) | Includes a realized net loss, pre-tax of $4 million ($3 million after-tax) for the three months ended December 31, 2023 (2022 $5 million net loss, pre-tax and $4 million loss, after-tax) and a $11 million net loss, pre-tax ($8 million after-tax) for the year ended December 31, 2023 (2022 $6 million net loss, pre-tax and $5 million loss after-tax) on FX hedges, as discussed above. |
(4) | Excludes a MTM gain, after-tax of $15 million for the three months ended December 31, 2023 (2022 $9 million gain, after-tax) and a MTM gain, after-tax of $20 million for the year ended December 31, 2023 (2022 $12 million loss, after-tax). |
Liquidity and Capital Resources
The Company generates internally sourced cash from its various regulated and non-regulated energy investments. Utility customer bases are diversified by both sales volumes and revenues among customer classes. Emeras non-regulated businesses provide diverse revenue streams and counterparties to the business. Circumstances that could affect the Companys ability to generate cash include changes to global macro-economic conditions, downturns in markets served by Emera, impact of fuel commodity price changes on collateral requirements and timely recoveries of fuel costs from customers, the loss of one or more large customers, regulatory decisions affecting customer rates and the recovery of regulatory assets, and changes in environmental legislation. Emeras 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.
Emeras future liquidity and capital needs will be predominately for working capital requirements, ongoing rate base investment, business acquisitions, greenfield development, dividends and debt servicing. Emera has an approximate $9 billion capital investment plan over the 2024 through 2026 period with approximately $2 billion of additional potential capital investments over the same period. Capital investments at Emeras regulated utilities are subject to regulatory approval.
EMERA 2023 ANNUAL REPORT | 37 |
Managements Discussion & Analysis
Emera plans to use cash from operations, debt raised at the utilities, equity, and select asset sales to support normal operations, repayment of existing debt, and capital requirements. Debt raised at certain of the Companys utilities is subject to applicable regulatory approvals. Generally, equity requirements in support of the Companys capital investment plan are expected to be funded through issuance of preferred equity and issuance of common equity through Emeras DRIP and ATM programs.
Emera has credit facilities with varying maturities that cumulatively provide $5.3 billion of credit, with approximately $2.3 billion undrawn and available at December 31, 2023. The Company was holding a cash balance of $588 million at December 31, 2023. For further discussion, refer to the Debt Management section below. For additional information regarding the credit facilities, refer to notes 23 and 25 in the consolidated financial statements.
CONSOLIDATED CASH FLOW HIGHLIGHTS
Significant changes in the Consolidated Statements of Cash Flows between the years ended December 31, 2023 and 2022 include:
millions of dollars |
2023 | 2022 | $ Change | |||||||||
Cash, cash equivalents and restricted cash, beginning of period |
$ | 332 | $ | 417 | $ | (85 | ) | |||||
Provided by (used in): |
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Operating cash flow before changes in working capital |
2,336 | 1,147 | 1,189 | |||||||||
Change in working capital |
(95 | ) | (234 | ) | 139 | |||||||
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Operating activities |
$ | 2,241 | $ | 913 | $ | 1,328 | ||||||
Investing activities |
(2,917 | ) | (2,569 | ) | (348 | ) | ||||||
Financing activities |
939 | 1,555 | (616 | ) | ||||||||
Effect of exchange rate changes on cash, cash equivalents and restricted cash |
(7 | ) | 16 | (23 | ) | |||||||
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Cash, cash equivalents, and restricted cash, end of period |
$ | 588 | $ | 332 | $ | 256 | ||||||
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Cash Flow from Operating Activities
Net cash provided by operating activities increased $1,328 million to $2,241 million for the year ended December 31, 2023, compared to $913 million in 2022.
Cash from operations before changes in working capital increased $1,189 million for the year ended December 31, 2023. This increase was due to higher fuel clause recoveries and favourable changes in the storm reserve balance at TEC, decreased fuel for generation and purchased power expense at NSPI driven by the decreased Nova Scotia Cap-and-Trade Program provision and a distribution received from the LIL partnership. This was partially offset by a decrease in regulatory liabilities due to 2022 gas hedge settlements at NMGC, and receipt of the TGH award in 2022.
Changes in working capital increased operating cash flows by $139 million for the year ended December 31, 2023. This increase was due to favourable changes in accounts receivable at NMGC due to receipt of its 2022 gas hedge settlement, favourable changes in cash collateral positions at Emera Energy, favourable changes in natural gas inventory at EES in 2023, and the required prepayment of income taxes and related interest in 2022 at NSPI. These increases were offset by the timing of accounts payable payments at NSPI, TEC and NMGC, unfavourable changes in cash collateral positions at NSPI, and decreased accrual for the Nova Scotia Cap-and-Trade emissions compliance charges at NSPI.
Cash Flow Used in Investing Activities
Net cash used in investing activities increased $348 million to $2,917 million for the year ended December 31, 2023, compared to $2,569 million in 2022. The increase was due to higher capital investment in 2023.
Capital expenditures for the year ended December 31, 2023, including AFUDC, were $2,976 million compared to $2,646 million in 2022. Details of 2023 capital spending by segment are shown below:
| $1,771 million Florida Electric Utility (2022 $1,481 million); |
| $461 million Canadian Electric Utilities (2022 $518 million); |
| $673 million Gas Utilities and Infrastructure (2022 $578 million); |
| $63 million Other Electric Utilities (2022 $63 million); and |
| $8 million Other (2022 $6 million). |
38 | EMERA 2023 ANNUAL REPORT |
Managements Discussion & Analysis
Cash Flow from Financing Activities
Net cash provided by financing activities decreased $616 million to $939 million for the year ended December 31, 2023, compared to $1,555 million in 2022. This decrease was due to lower proceeds from long-term debt at TEC, higher repayment of short-term debt at TEC, lower proceeds from short-term debt at TECO Finance and Emera, and higher repayments of committed credit facilities at NSPI. This was partially offset by proceeds from long-term debt at PGS and NSPI, retirement of long-term debt at TEC in 2022, and higher issuance of common stock.
WORKING CAPITAL
As at December 31, 2023, Emeras cash and cash equivalents were $567 million (2022 $310 million) and Emeras investment in non-cash working capital was $831 million (2022 $1,173 million). Of the cash and cash equivalents held at December 31, 2023, $482 million was held by Emeras foreign subsidiaries (2022 $250 million). A portion of these funds are invested in countries that have certain exchange controls, approvals, and processes for repatriation. Such funds are available to fund local operating and capital requirements unless repatriated.
CONTRACTUAL OBLIGATIONS
As at December 31, 2023, contractual commitments for each of the next five years and in aggregate thereafter consisted of the following:
millions of dollars |
2024 | 2025 | 2026 | 2027 | 2028 | Thereafter | Total | |||||||||||||||||||||
Long-term debt principal |
$ | 1,670 | $ | 264 | $ | 3,047 | $ | 666 | $ | 525 | $ | 12,318 | $ | 18,490 | ||||||||||||||
Interest payment obligations (1) |
836 | 807 | 719 | 626 | 587 | 7,438 | 11,013 | |||||||||||||||||||||
Transportation (2) |
696 | 495 | 405 | 388 | 338 | 2,597 | 4,919 | |||||||||||||||||||||
Purchased power (3) |
274 | 249 | 263 | 312 | 312 | 3,435 | 4,845 | |||||||||||||||||||||
Fuel, gas supply and storage |
556 | 215 | 62 | | 5 | | 838 | |||||||||||||||||||||
Capital projects |
778 | 111 | 70 | 1 | | | 960 | |||||||||||||||||||||
Asset retirement obligations |
10 | 2 | 1 | 1 | 2 | 407 | 423 | |||||||||||||||||||||
Pension and post-retirement obligations (4) |
28 | 29 | 38 | 47 | 32 | 155 | 329 | |||||||||||||||||||||
Equity investment commitments (5) |
240 | | | | | | 240 | |||||||||||||||||||||
Other |
154 | 147 | 56 | 46 | 35 | 221 | 659 | |||||||||||||||||||||
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$ | 5,242 | $ | 2,319 | $ | 4,661 | $ | 2,087 | $ | 1,836 | $ | 26,571 | $ | 42,716 | |||||||||||||||
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(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, 2023, including any expected required payment under associated swap agreements. |
(2) | Purchasing commitments for transportation of fuel and transportation capacity on various pipelines. Includes a commitment of $134 million related to a gas transportation contract between PGS and SeaCoast through 2040. |
(3) | Annual requirement to purchase electricity production from IPPs or other utilities over varying contract lengths. |
(4) | The estimated contractual obligation is calculated as the current legislatively required contributions to the registered funded pension plans (excluding the possibility of wind-up), plus the estimated costs of further benefit accruals contracted under NSPIs Collective Bargaining Agreement and estimated benefit payments related to other unfunded benefit plans. |
(5) | Emera has a commitment to make equity contributions to the LIL related to an investment true up in 2024 and sustaining capital contributions over the life of the partnership. The commercial agreements between Emera and Nalcor require true ups to finalize the respective investment obligations of the parties in relation the Maritime Link and LIL which is expected to be approximately $240 million in 2024. In addition, Emera has future commitments to provide sustaining capital to the LIL for routine capital and major maintenance. |
NSPI has a contractual obligation to pay NSPML for use of the Maritime Link over approximately 38 years from its January 15, 2018 in-service date. In February 2022, the UARB issued its decision and Board Order approving NSPMLs requested rate base of approximately $1.8 billion. In December 2023, the UARB approved collection of up to $164 million from NSPI for recovery of Maritime Link costs in 2024. The timing and amounts payable to NSPML for the remainder of the 38-year commitment period are subject to UARB approval.
EMERA 2023 ANNUAL REPORT | 39 |
Managements Discussion & Analysis
Construction of the LIL is complete and the Newfoundland Electrical System Operator confirmed the asset to be operating suitably to support reliable system operation and full functionality at 700MW, which was validated by the Government of Canadas Independent Engineer issuing its Commissioning Certificate on April 13, 2023.
Emera has committed to obtain certain transmission rights for Nalcor, if requested, to enable it to transmit energy which is not otherwise used in Newfoundland and Labrador or Nova Scotia. Nalcor has the right to transmit this energy from Nova Scotia to New England energy markets effective August 15, 2021 and continuing for 50 years. As transmission rights are contracted, the obligations are included within Other in the above table.
FORECASTED CONSOLIDATED CAPITAL EXPENDITURES
The 2024 forecasted consolidated capital investments are as follows:
millions of dollars |
Florida Electric Utility |
Canadian Electric Utilities |
Gas Utilities and Infrastructure |
Other Electric Utilities |
Other | Total | ||||||||||||||||||
Generation |
$ | 266 | $ | 143 | $ | | $ | 30 | $ | | $ | 439 | ||||||||||||
New renewable generation |
280 | | | | | 280 | ||||||||||||||||||
Electric transmission |
119 | 88 | | | | 207 | ||||||||||||||||||
Electric distribution |
496 | 142 | | 58 | | 696 | ||||||||||||||||||
Gas transmission and distribution |
| | 566 | | | 566 | ||||||||||||||||||
Facilities, equipment, vehicles, and other |
567 | 63 | 51 | 17 | 4 | 702 | ||||||||||||||||||
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$ | 1,728 | $ | 436 | $ | 617 | $ | 105 | $ | 4 | $ | 2,890 | |||||||||||||
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DEBT MANAGEMENT
In addition to funds generated from operations, Emera and its subsidiaries have, in aggregate, access to committed syndicated revolving and non-revolving bank lines of credit in either CAD or USD per the table below.
millions of Canadian dollars (unless otherwise indicated) |
Maturity | Credit Facilities |
Utilized | Undrawn and Available |
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Emera Unsecured committed revolving credit facility |
June 2027 | $ | 900 | $ | 265 | $ | 635 | |||||||||
TEC (in USD) Unsecured committed revolving credit facility |
December 2026 | 800 | 707 | 93 | ||||||||||||
NSPI Unsecured committed revolving credit facility |
December 2027 | 800 | 332 | 468 | ||||||||||||
Emera Unsecured non-revolving facility |
December 2024 | 400 | 400 | | ||||||||||||
Emera Unsecured non-revolving facility |
February 2024 | 400 | 200 | 200 | ||||||||||||
Emera Unsecured non-revolving facility |
August 2024 | 400 | 400 | | ||||||||||||
TECO Finance (in USD) Unsecured committed revolving credit facility |
December 2026 | 400 | 185 | 215 | ||||||||||||
NSPI Unsecured non-revolving facility |
July 2024 | 400 | 400 | | ||||||||||||
PGS (in USD) Unsecured revolving facility |
December 2028 | 250 | 55 | 195 | ||||||||||||
TEC (in USD) Unsecured revolving facility |
February 2024 | 200 | | 200 | ||||||||||||
TEC (in USD) Unsecured revolving facility |
April 2024 | 200 | | 200 | ||||||||||||
NMGC (in USD) Unsecured revolving credit facility |
December 2026 | 125 | 21 | 104 | ||||||||||||
NMGC (in USD) Unsecured non-revolving facility |
March 2024 | 23 | 23 | | ||||||||||||
Other (in USD) Unsecured committed revolving credit facilities |
Various | 21 | 6 | 15 | ||||||||||||
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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, 2023. Emeras significant covenant is listed below:
Financial Covenant | Requirement | As at December 31, 2023 |
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Emera |
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Syndicated credit facilities |
Debt to capital ratio | Less than or equal to 0.70 to 1 | 0.57 : 1 | |||||||||
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40 | EMERA 2023 ANNUAL REPORT |
Managements Discussion & Analysis
Recent significant financing activity for Emera and its subsidiaries are discussed below by segment:
Florida Electric Utilities
On January 30, 2024, TEC issued $500 million USD of senior unsecured bonds that bear interest at 4.90 per cent with a maturity date of March 1, 2029. Proceeds from the issuance were primarily used for the repayment of short-term borrowings outstanding under the 5-year credit facility. Therefore, $497 million USD of short-term borrowings that was repaid was classified as long-term debt at December 31, 2023.
On November 24, 2023, TEC repaid its $400 million USD unsecured non-revolving facility, which expired on December 13, 2023.
On April 3, 2023, TEC entered into a 364-day, $200 million USD senior unsecured revolving credit facility which matures on April 1, 2024. The credit agreement contains customary representations and warranties, events of default and financial and other covenants, and bears interest at a variable interest rate, based on either the term secured overnight financing rate (SOFR), Wells Fargos prime rate, the federal funds rate or the one-month SOFR, plus a margin. Proceeds from this facility will be used for general corporate purposes.
On March 1, 2023, TEC entered into a 364-day, $200 million USD senior unsecured revolving credit facility which matures on February 28, 2024. The credit facility contains customary representations and warranties, events of default and financial and other covenants, and bears interest at a variable interest rate, based on either the term SOFR, the Bank of Nova Scotias prime rate, the federal funds rate or the one-month SOFR, plus a margin. Proceeds from this facility will be used for general corporate purposes.
Canadian Electric Utilities
On March 24, 2023, NSPI issued $500 million in unsecured notes. The issuance included $300 million unsecured notes that bear interest at 4.95 per cent with a maturity date of November 15, 2032, and $200 million unsecured notes that bear interest at 5.36 per cent with a maturity date of March 24, 2053. Proceeds from these issuances were added to the general funds of the Company and applied primarily to refinance existing indebtedness, to finance capital investment and for general corporate purposes.
Gas Utilities and Infrastructure
On December 19, 2023, PGS completed an issuance of $925 million USD in senior notes. The issuance included $350 million USD senior notes that bear interest at 5.42 per cent with a maturity date of December 19, 2028, $350 million USD senior notes that bear interest at 5.63 per cent with a maturity date of December 19, 2033 and $225 million USD senior notes that bear interest at 5.94 per cent with a maturity date of December 19, 2053. Proceeds from these issuances were used to settle intercompany loan agreements with TEC for the assets and liabilities transferred to PGS as part of the reorganization of the gas division of Tampa Electric, effective on January 1, 2023.
On December 1, 2023, PGS entered into a $250 million USD senior unsecured revolving credit facility with a group of banks, maturing on December 1, 2028. PGS has the ability to request the lenders to increase their commitments under the credit facility by up to $100 million USD in the aggregate subject to agreement from participating lenders. The credit agreement contains customary representations and warranties, events of default and financial and other covenants, and bears interest at Bankers Acceptances or prime rate advances, plus a margin. Proceeds from these facilities will be used for general corporate purposes.
On October 19, 2023, NMGC issued $100 million USD in senior unsecured notes that bear interest at 6.36 per cent with a maturity date of October 19, 2033. Proceeds from the issuance were used to repay short-term borrowings.
Other Electric Utilities
On May 24, 2023, GBPC issued a $28 million USD non-revolving term loan that bears interest at 4.00 per cent with a maturity date of May 24, 2028. Proceeds from this issuance were used to repay GBPCs $28 million USD bond, which matured in May 2023.
EMERA 2023 ANNUAL REPORT | 41 |
Managements Discussion & Analysis
Other
On December 16, 2023, Emera amended its $400 million unsecured non-revolving facility to extend the maturity date from December 16, 2023 to December 16, 2024. There were no other changes in commercial terms from the prior agreement.
On August 18, 2023, Emera entered into a $400 million non-revolving term facility which matures on February 19, 2024. The credit agreement contains customary representations and warranties, events of default and financial and other covenants, and bears interest at Bankers Acceptances or prime rate advances, plus a margin. Proceeds from this facility will be used for general corporate purposes. On February 16, 2024, Emera extended the term of this agreement to a maturity date of February 19, 2025.
On June 30, 2023, Emera amended its $400 million unsecured non-revolving facility to extend the maturity date from August 2, 2023 to August 2, 2024. There were no other changes in commercial terms from the prior agreement.
On May 2, 2023, Emera issued $500 million in senior unsecured notes that bear interest at 4.84 per cent with a maturity date of May 2, 2030. The proceeds were used to repay Emeras $500 million unsecured fixed rate notes, which matured in June 2023.
CREDIT RATINGS
Emera and its subsidiaries have been assigned the following senior unsecured debt ratings:
Fitch |
S&P |
Moodys |
DBRS | |||||
Emera Inc. |
BBB (Negative) | BBB- (Negative) | Baa3 (Negative) | N/A | ||||
TEC |
A (Negative) | BBB+ (Negative) | A3 (Negative) | N/A | ||||
PGS (1) |
A (Negative) | N/A | N/A | N/A | ||||
NMGC |
BBB+ (Negative) | N/A | N/A | N/A | ||||
NSPI |
N/A | BBB- (Negative) | N/A | BBB (high)(stable) | ||||
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(1) | On November 10, 2023 Fitch Ratings (Fitch) assigned first-time long-term issuer default rating of A- to PGS and an instrument rating of A for its private placements of senior unsecured bonds. |
GUARANTEED DEBT
As of December 31, 2023, the Company had $2.75 billion USD (2022 $2.75 billion USD) senior unsecured notes (US Notes) outstanding.
The US Notes are fully and unconditionally guaranteed, on a joint and several basis, by Emera 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. Other subsidiaries of the Company do not guarantee the US Notes (such subsidiaries are referred to as the Non-Guarantor Subsidiaries); however, Emera has unrestricted access to the assets of consolidated entities.
In compliance with Rule 13-01 of Regulation S-X, the Company is including summarized financial information for Emera, Emera US Holdings Inc., and Emera US Finance LP (together, the Obligor Group), on a combined basis after transactions and balances between the combined entities have been eliminated. Investments in and equity earnings of the Non-Guarantor Subsidiaries have been excluded from the summarized financial information.
The Obligor Group was not determined using geographic, service line or other similar criteria and, as a result, the summarized financial information includes portions of Emeras domestic and international operations. Accordingly, this basis of presentation is not intended to present Emeras financial condition or results of operations for any purpose other than to comply with the specific requirements for guarantor reporting.
Summarized Statement of Income (Loss)
The Company recognized income related to guaranteed debt under the following categories:
For the | Year ended December 31 | |||||||
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2023 | 2022 | ||||||
Loss from operations |
$ | (62 | ) | $ | (73 | ) | ||
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Net gains (losses) (1) |
$ | 349 | $ | (131 | ) | |||
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(1) | Includes $750 million (2022 $262 million) in interest and dividend income, net, from non-guarantor subsidiaries. |
42 | EMERA 2023 ANNUAL REPORT |
Managements Discussion & Analysis
Summarized Balance Sheet
The Company has the following categories on the balance sheet related to guaranteed debt:
As at | December 31 | |||||||
millions of dollars |
2023 | 2022 | ||||||
Current assets (1) |
$ | 223 | $ | 172 | ||||
Goodwill |
5,871 | 6,012 | ||||||
Other assets (2) |
6,243 | 6,402 | ||||||
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Total assets (3) |
$ | 12,337 | $ | 12,586 | ||||
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Current liabilities (4) |
$ | 1,451 | $ | 1,903 | ||||
Long-term liabilities (5) |
6,815 | 6,431 | ||||||
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Total liabilities |
$ | 8,266 | $ | 8,334 | ||||
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(1) | Includes $179 million (2022 $144 million) in amounts due from non-guarantor subsidiaries. |
(2) | Includes $5,941 million (2022 $6,058 million) in amounts due from non-guarantor subsidiaries. |
(3) | Excludes investments in non-guarantor subsidiaries. Consolidated Emera total assets are $39,480 million (2022 $39,742 million). |
(4) | Includes $411 million (2022 $392 million) due to non-guarantor subsidiaries. |
(5) | Includes $619 million (2022 $769 million) due to non-guarantor subsidiaries. |
OUTSTANDING STOCK DATA
Common Stock
Issued and outstanding: |
millions of shares |
millions of dollars |
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Balance, December 31, 2022 |
269.95 | $ | 7,762 | |||||
Issuance of common stock under ATM program (1) |
8.29 | 397 | ||||||
Issued under the DRIP, net of discounts |
5.26 | 272 | ||||||
Senior management stock options exercised and Employee Share Purchase Plan |
0.62 | 31 | ||||||
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Balance, December 31, 2023 |
284.12 | $ | 8,462 | |||||
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(1) | For the year ended December 31,2023, 8,287,037 common shares were issued under Emeras ATM program at an average price of $48.27 per share for gross proceeds of $400 million ($397 million net of after-tax issuance costs). As at December 31,2023, an aggregate gross sales limit of $200 million remained available for issuance under the ATM program. |
As at February 20, 2024, the amount of issued and outstanding common shares was 285.8 million.
If all outstanding stock options were converted as at February 20, 2024, an additional 3.1 million common shares would be issued and outstanding.
ATM Equity Program
On October 3, 2023, Emera filed a short form base shelf prospectus, primarily in support of the renewal of its ATM Program in Q4 2023 that will allow the Company to issue up to $600 million of common shares from treasury to the public from time to time, at the Companys discretion, at the prevailing market price. This ATM Program is expected to remain in effect until November 4, 2025.
Preferred Stock
As at February 20, 2024, Emera had the following preferred shares issued and outstanding: Series A 4.9 million; Series B 1.1 million; Series C 10.0 million; Series E 5.0 million; Series F 8.0 million; Series H 12.0 million; Series J 8.0 million, and Series L 9.0 million. Emeras preferred shares do not have voting rights unless the Company fails to pay, in aggregate, eight quarterly dividends.
On July 6, 2023, Emera announced it would not redeem the 10 million outstanding Cumulative Rate Reset Preferred Shares, Series C (Series C Shares) or the 12 million outstanding Cumulative Minimum Rate Reset First Preferred Shares, Series H (Series H Shares) on August 15, 2023.
EMERA 2023 ANNUAL REPORT | 43 |
Managements Discussion & Analysis
On August 4, 2023, Emera announced after having taken into account all conversion notices received from holders, no Series C Shares were converted into Cumulative Floating Rate First Preferred Shares, Series D Shares and no Series H shares were converted into Cumulative Floating Rate First Preferred Shares, Series I shares. The holders of the Series C Shares are entitled to receive a dividend of 6.434 per cent per annum on the Series C Shares during the five-year period commencing on August 15, 2023, and ending on (and inclusive of) August 14, 2028 ($0.40213 per Series C Share per quarter). The holders of the Series H Shares are entitled to receive a dividend of 6.324 per cent per annum on the Series H Shares during the five-year period commencing on August 15, 2023, and ending on (and inclusive of) August 14, 2028 ($0.39525 per Series H Share per quarter).
Pension Funding
For funding purposes, Emera determines required contributions to its largest defined benefit (DB) pension plans based on smoothed asset values. This reduces volatility in the cash funding requirement as the impact of investment gains and losses are recognized over a three-year period. Expected cash flow for DB pension plans is $34 million in 2024 (2023 $42 million). All pension plan contributions are tax deductible and will be funded with cash from operations.
Emeras DB 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 Companys goal of preserving capital with 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 each pension plans investment policy and governance framework. The asset allocation includes investments in the assets of domestic and global equities, domestic and global bonds and short-term investments. The Company reviews investment manager performance on a regular basis and adjusts the plans asset mixes as needed in accordance with the pension plans investment policy.
Emeras projected contributions to defined contribution pension plans are $46 million for 2024 (2023 $45 million).
DEFINED BENEFIT PENSION PLAN SUMMARY
in millions of dollars |
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Plans by region |
TECO Energy | NSPI | Caribbean | Total | ||||||||||||
Assets as at December 31, 2023 |
$ | 907 | $ | 1,381 | $ | 10 | $ | 2,298 | ||||||||
Accounting obligation at December 31, 2023 |
$ | 896 | $ | 1,361 | $ | 16 | $ | 2,273 | ||||||||
Accounting expense (income) during fiscal 2023 |
$ | 4 | $ | (16 | ) | $ | 1 | $ | (11 | ) | ||||||
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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, 2023 totalled $200 million (2022 $200 million). The securities are held in trust for an affiliate of the Province of Nova Scotia. Approximately 66 per cent of the defeasance portfolio consists of investments in the related debt, eliminating all risk associated with this portion of the portfolio.
GUARANTEES AND LETTERS OF CREDIT
Emera has guarantees and letters of credit on behalf of third parties outstanding. The following significant guarantees and letters of credit are not included within the Consolidated Balance Sheets as at December 31, 2023:
TECO Energy has issued a guarantee in connection with SeaCoasts 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 was terminated on January 1, 2022. In the event TECO Energys and Emeras long-term senior unsecured credit ratings are downgraded below investment grade by Moodys or S&P, TECO Energy would be required to provide its counterparty a letter of credit or cash deposit of $27 million USD.
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Managements Discussion & Analysis
TECO Energy issued a guarantee in connection with SeaCoasts performance obligations under a firm service agreement, which expires December 31, 2055, subject to two extension terms at the option of the counterparty with a final expiration date of December 31, 2071. The guarantee is for a maximum potential amount of $13 million USD if SeaCoast fails to pay or perform under the firm service agreement. In the event that TECO Energys long-term senior unsecured credit ratings are downgraded below investment grade by Moodys or S&P, TECO Energy would need to provide either a substitute guarantee from an affiliate with an investment grade credit rating or a letter of credit or cash deposit of $13 million USD.
Emera Inc. has issued a guarantee of $66 million USD relating to outstanding notes of ECI. This guarantee will automatically terminate on the date upon which the obligations have been repaid in full.
NSPI has issued guarantees on behalf of its subsidiary, NS Power Energy Marketing Incorporated, in the amount of $104 million USD (2022 $119 million USD) with terms of varying lengths.
The Company has standby letters of credit and surety bonds in the amount of $103 million USD (December 31, 2022 $145 million USD) to third parties that have extended credit to Emera and its subsidiaries. These letters of credit and surety bonds typically have a one-year term and are renewed annually as required.
Emera Inc., on behalf of NSPI, has a standby letter of credit to secure obligations under a supplementary retirement plan. The expiry date of this letter of credit was extended to June 2024. The amount committed as at December 31, 2023 was $56 million (December 31, 2022 $63 million).
Dividend Payout Ratio
Emera has provided annual dividend growth guidance of four to five per cent through 2026. The Company targets a long-term dividend payout ratio of adjusted net income of 70 to 75 per cent and, while the payout ratio is likely to exceed that target through and beyond the forecast period, it is expected to return to that range over time. Emeras common share dividends paid in 2023 were $2.7875 ($0.6900 in Q1, Q2, and Q3 and $0.7175 in Q4) per common share and $2.6775 ($0.6625 in Q1, Q2, and Q3 and $0.6900 in Q4) per common share for 2022, representing a dividend payout ratio of 78 per cent in 2023 (2022 75 per cent) and a dividend payout ratio of adjusted net income of 94 per cent in 2023 (2022 83 per cent).
On September 20, 2023, the Board approved an increase in the annual common share dividend rate to $2.87 from $2.76 per common share. The first quarterly dividend payment at the increased rate was paid on November 15, 2023.
Transactions with Related Parties
In the ordinary course of business, Emera provides energy 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. NSPIs expense is reported in Regulated fuel for generation and purchased power, totalling $163 million for the year ended December 31, 2023 (2022 $157 million). NSPML is accounted for as an equity investment, and therefore corresponding earnings related to this revenue are reflected in Income from equity investments. For further details, refer to the Business Overview and Outlook Canadian Electric Utilities ENL and Contractual Obligations sections. |
| Natural gas transportation capacity purchases from M&NP are reported in the Consolidated Statements of Income. Purchases from M&NP reported net in Operating revenues, Non-regulated, totalled $14 million for the year ended December 31, 2023 (2022 $9 million). |
There were no significant receivables or payables between Emera and its associated companies reported on Emeras Consolidated Balance Sheets as at December 31, 2023 and at December 31, 2022.
EMERA 2023 ANNUAL REPORT | 45 |
Managements Discussion & Analysis
Enterprise Risk and Risk Management
Emera has an enterprise-wide risk management process, overseen by its Enterprise Risk Management Committee (ERMC) and monitored by the Board, to ensure an effective, consistent and coherent approach to risk management. Certain risk management activities for Emera are overseen by the ERMC to ensure such risks are appropriately identified, assessed, monitored and subject to appropriate controls.
The Board has a Risk and Sustainability Committee (RSC) with a mandate to assist the Board in carrying out its risk and sustainability oversight responsibilities. The RSCs mandate includes oversight of the Companys Enterprise Risk Management framework, including the identification, assessment, monitoring and management of enterprise risks. It also includes oversight of the Companys approach to sustainability and its performance relative to its sustainability objectives.
The Companys financial risk management activities are focused on those areas that most significantly impact profitability, quality and consistency of income, and cash flow. Emeras risk management focus extends to key operational risks including safety and environment, which represent core values of Emera. In this section, Emera describes the principal risks that management believes could materially affect its business, revenues, operating income, net income, net assets, liquidity or capital resources. The nature of risk is such that no list is comprehensive, and other risks may arise or risks not currently considered material may become material in the future.
REGULATORY AND POLITICAL RISK
The Companys rate-regulated subsidiaries and certain investments subject to significant influence are subject to risk of the recovery of costs and investments. Regulatory and political risk can include changes in regulatory frameworks, shifts in government policy, legislative changes, and regulatory decisions.
As cost-of-service utilities with an obligation to serve customers, Emeras utilities operate under formal regulatory frameworks, and must obtain regulatory approval to change or add rates and/or riders. Emera also holds investments in entities in which it has significant influence, and which are subject to regulatory and political risk including NSPML, LIL, and M&NP. As a regulated Group II pipeline, the tolls of Brunswick Pipeline are regulated by the CER on a complaint basis, as opposed to the regulatory approval process described above. In the absence of a complaint, the CER does not normally undertake a detailed examination of Brunswick Pipelines tolls, which are subject to a firm service agreement, expiring in 2034, with Repsol Energy North America Canada Partnership.
Regulators administer the regulatory frameworks covering material aspects of the utilities businesses, including applying market-based tests to determine the appropriate customer rates and/or riders, the underlying allowed ROEs, deemed capital structures, capital investment, the terms and conditions for the provision of service, performance standards, and affiliate transactions. Regulators also review the prudency of costs and other decisions that impact customer rates and reliability of service and work to ensure the financial health of the utility for the benefit of customers. Costs and investments can be recovered upon approval by the respective regulator as an adjustment to rates and/or riders, which normally require a public hearing process or may be mandated by other governmental bodies. 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. Regulatory decisions, legislative changes, and prolonged delays in the recovery of costs or regulatory assets could result in decreased rate affordability for customers and could materially affect Emera and its utilities.
Emeras utilities generally manage this risk through transparent regulatory disclosure, ongoing stakeholder and government consultation, and multi-party engagement on aspects such as utility operations, regulatory audits, rate filings and capital plans. The subsidiaries work to establish collaborative relationships with regulatory stakeholders, including customer representatives, both through its approach to filings and additional efforts with technical conferences and, where appropriate, negotiated settlements.
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Managements Discussion & Analysis
Changes in government and shifts in government policy and legislation can impact the commercial and regulatory frameworks under which Emera and its subsidiaries operate. This includes initiatives regarding deregulation or restructuring of the energy industry. Deregulation or restructuring of the energy industry may result in increased competition and unrecovered costs that could adversely affect the Companys operations, net income and cash flows. State and local policies in some United States jurisdictions have sought to prevent or limit the ability of utilities to provide customers the choice to use natural gas while in other jurisdictions policies have been adopted to prevent limitations on the use of natural gas. Changes in applicable state or local laws and regulations, including electrification legislation, could adversely impact PGS and NMGC.
Emera cannot predict future legislative, policy, or regulatory changes, whether caused by economic, political or other factors, or its ability to respond in an effective and timely manner or the resulting compliance costs. Government interference in the regulatory process can undermine regulatory stability, predictability, and independence, and could have a material adverse effect on the Company.
GLOBAL CLIMATE CHANGE RISK
The Company is subject to risks that may arise from the impacts of climate change. There is increasing public concern about climate change and growing support for reducing carbon dioxide emissions. Municipal, state, provincial and federal governments have been setting policies and enacting laws and regulations to deal with climate change impacts in a variety of ways, including decarbonization initiatives and promotion of cleaner energy and renewable energy generation of electricity. Refer to Changes in Environmental Legislation risk below. Insurance companies have begun to limit their exposure to coal-fired electricity generation and are evaluating the medium and long-term impacts of climate change which may result in fewer insurers, more restrictive coverage and increased premiums. Refer to the Insurance section below and Uninsured Risk.
Climate change may lead to increased frequency and intensity of events and related impacts such as hurricanes, ice and other storms, heavy rainfall, cyclones, extreme winds, wildfires, flooding and droughts. The potential impacts of climate change, such as rising sea levels and larger storm surges from more intense hurricanes, can combine to produce even greater damage to coastal generation and other facilities. Climate change is also characterized by rising global temperatures. Increased air temperatures may bring increased frequency and severity of wildfires within the Companys service territories. Refer to Weather Risk and System Operating and Maintenance Risks.
The Companys long-term capital investment plan includes significant investment across the portfolio in renewable and cleaner generation, infrastructure modernization, storm hardening, energy storage and customer-focused technologies. All these initiatives contribute toward mitigating the potential impacts of climate change. The Company continues to engage with government, regulators, industry partners and stakeholders to share information and participate in the development of climate change related policies and initiatives.
Physical Impacts:
The Company is subject to physical risks that arise, or may arise, from global climate change, including damage to operating assets from more frequent and intense weather events and from wildfires due to warming air temperatures and increasing drought conditions. Substantially all of the Companys fossil fueled generation assets are located at or near coastal sites and, as such, are exposed to the separate and combined effects of rising sea levels and increasing storm intensity, including storm surges and flooding. Refer to Weather Risk for further information.
These risks are mitigated to an extent through features such as flood walls at certain plants and through the location of plants on higher ground. Planned investments in under-grounding parts of the electricity infrastructure contribute to risk mitigation, as does insurance coverage (for assets other than electricity transmission and distribution assets). In addition, implementation of regulatory mechanisms for recovery of costs, such as storm reserves and regulatory deferral accounts, help smooth out the recovery of storm restoration costs over time.
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Managements Discussion & Analysis
Reputation:
Failure to address issues related to climate change could affect Emeras reputation with stakeholders, its ability to operate and grow, and the Companys access to, and cost of, capital. Refer to Liquidity and Capital Market Risk. The Company seeks to mitigate this in part by moving away from higher-carbon generation in favour of lower-carbon generation and non-emitting renewable generation.
Supply Chain:
Changing carbon-related costs, policy and regulatory changes and shifts in supply and demand factors could lead to more expensive or more scarce products and services that are required by the Company in its operations. This could lead to supply shortages, delivery delays and the need to source alternate products and services. The Company seeks to mitigate these risks through close monitoring of such developments and adaptive changes to supply chain procurement strategies. Refer to Supply Chain Risk and Uninsured Risk.
Insurance:
Given concerns regarding carbon-emitting generation, assets and businesses may, over time, become difficult (or uneconomic) to insure in commercial insurance markets. In the short term, this may be mitigated through increased investment in engineered protection or alternative risk financing (such as funded self-insurance or regulatory structures, including storm reserves). Longer-term mitigation may be achieved through infrastructure siting decisions and further engineered protections. This risk may also be mitigated through the continued transition away from high-carbon generation sources to sources with low or zero carbon dioxide emissions.
Policy:
Government and regulatory initiatives, including greenhouse gas emissions standards, air emissions standards and generation mix standards, are being proposed and adopted in many jurisdictions in response to concerns regarding the effects of climate change. In some jurisdictions, government policy has included timelines for mandated shutdowns of coal generating facilities, percentage of electricity generation from renewables, carbon pricing, emissions limits and cap and trade mechanisms. Over the medium and longer terms, this could potentially lead to a significant portion of hydrocarbon infrastructure assets being subject to additional regulation and limitations in respect of GHG emissions and operations.
The Company is subject to climate-related and environmental legislative and regulatory requirements. Such legislative and regulatory initiatives could adversely affect Emeras operations and financial performance. Refer to Regulatory and Political Risk and Changes in Environmental Legislation risk. The Company seeks to mitigate these risks through active engagement with governments and regulators to pursue transition strategies that meet the needs of customers, stakeholders and the Company. This has included NSPIs participation in negotiated equivalency agreements in Nova Scotia to provide for an affordable transition to lower-carbon generation. Equivalency agreements allow NSPI to achieve compliance with federal GHG emissions regulations by meeting provincial legislative and regulatory requirements as they are deemed to be equivalent. There is no guarantee that such equivalency agreements will be renewed or remain in force in the future.
Regulatory:
Depending on the regulatory response to government legislation and regulations, the Company may be exposed to the risk of reduced recovery through rates in respect of the affected assets. Valuation impairments could result from such regulatory outcomes. Mitigation efforts in respect of these risks include active engagement with policy makers and regulators to find mechanisms to avoid such impacts while being responsive to customers and stakeholders objectives.
Legal:
The Company could face litigation or regulatory action related to environmental harms from carbon dioxide emissions or climate change public disclosure issues. The Company addresses these risks through compliance with all relevant laws, emissions reduction strategies, and public disclosure of climate change risks.
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Managements Discussion & Analysis
Water Resources:
For thermal plants requiring cooling water, reduced availability of water resulting from climate change could adversely impact operations or the costs of operations. The Company seeks ways to reduce and recycle water as it does in its Polk power plant in Florida, where recovered and treated wastewater is used in operations to reduce reliance on fresh water supplies in an area where water is not as abundant as in other markets.
The Company operates hydroelectric generation in certain of its markets. Such generation depends on availability of water and the hydrological profile of water sources. Changes in precipitation patterns, water temperatures and air temperatures could adversely affect the availability of water and consequently the amount of electricity that may be produced from such facilities. The Company is reinvesting in the efficiency of certain hydroelectric generation facilities to increase generation capacity and continues to monitor changing hydrology patterns. Such issues may also affect the availability of purchased power from third- party owned hydroelectricity sources.
WEATHER RISK
The Company is subject to risks that arise or may arise from weather including seasonal variations impacting energy sales, more frequent and intense weather events, changing air temperatures, wildfires and extreme weather conditions associated with climate change. Refer to Global Climate Change Risk.
Fluctuations in the amount of electricity or natural gas used by customers can vary significantly in response to seasonal changes in weather and could impact the operations, results of operations, financial condition, and cash flows of the Companys utilities. For example, TEC could see lower demand in summer months if temperatures are cooler than expected. Further, extreme weather conditions such as hurricanes and other severe weather conditions which may be associated with climate change could cause these seasonal fluctuations to be more pronounced. In the absence of a regulatory recovery mechanism for unanticipated costs, such events could influence the Companys results of operations, financial conditions or cash flows.
Extreme weather events create a risk of physical damage to the Companys assets. High winds can impact structures and cause widespread damage to transmission and distribution infrastructure, solar generation, and wind powered generation. Higher frequency and severity of weather events increase the likelihood of longer power outages and more fuel supply disruptions. Increased frequency and intensity of flooding and storm surge could adversely affect the operations of utilities and in particular generation assets. The impact of extreme weather events would be amplified if the same events affect multiple utilities.
Each of Emeras regulated electric utilities have programs for storm hardening of transmission and distribution facilities to minimize damage, but there can be no assurance that these measures will fully mitigate the risk. This risk to transmission and distribution facilities is typically not insured, and as such the restoration cost is generally recovered through regulatory processes, either in advance through reserves or designated self-insurance funds, or after the fact through the establishment of regulatory assets. Recovery is not assured and is subject to prudency review. The risk to generation assets is, in part, mitigated through the design, siting, construction and maintenance of such facilities, regular risk assessments, engineered mitigation, emergency storm response plans, and insurance.
High winds and lack of precipitation increase the risk of wildfires resulting from the Companys infrastructure or for which the Company may otherwise have responsibility. The risk of wildfires is addressed primarily through asset management programs for natural gas transmission and distribution operations, and asset management, storm hardening, and vegetation management programs for electric utilities, but there can be no assurance that these measures will fully mitigate the risk. If it is found to be responsible for such a fire, the Company could suffer material costs, losses and damages, all or some of which may not be recoverable through insurance, legal, regulatory cost recovery or other processes. If not recovered through these means, they could materially affect Emeras business, access to capital, financial condition and results of operations 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.
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Managements Discussion & Analysis
CHANGES IN ENVIRONMENTAL LEGISLATION
Emera is subject to regulation by federal, provincial, state, regional and local authorities regarding environmental matters, primarily related to its utility operations. This includes laws setting GHG emissions standards and air emissions standards. Emera is also subject to laws regarding waste management, wastewater discharges and aquatic and terrestrial habitats.
Changes to GHG emissions standards and air emissions standards could adversely affect Emeras operations and financial performance.
Both the Government of Nova Scotia and the Government of Canada have enacted or introduced legislation that includes goals of net-zero GHG emissions by 2050. The Province of Nova Scotia has established targets with respect to the percentage of renewable energy in NSPIs generation mix, reductions in GHG emissions, as well as the goal to phase out coal-fired electricity generation by 2030. Failure to meet such goals by 2030 could result in material fines, penalties, other sanctions and adverse reputational impacts. NSPI continues to work with both the provincial and federal governments on measures to seek to address their carbon reduction goals. Within Emeras natural gas utilities, there are ongoing efforts to reduce methane and carbon dioxide emissions through replacement of aging infrastructure, more efficient operations, operational and supply chain optimization, renewable natural gas projects, and support of public policy initiatives that address the effects of climate change.
In 2023, the United States Environmental Protection Agency proposed new carbon emission standards for fossil fuel-fired power plants and the Government of Canada released draft Clean Electricity Regulations which propose limitations on the use of natural gas generation. Until final rules are issued, it is not certain what the impact will be on the Company and its operations.
These and other legislative or regulatory changes could influence decisions regarding capital investment, early retirement of generation facilities and may result in stranded costs if the Company is not able to fully recover the costs and investment in the affected generation assets. Recovery is not assured and is subject to prudency review. Legislative or regulatory changes may curtail sales of natural gas to new customers, which could reduce future customer growth in Emeras natural gas businesses. Stricter environmental laws and enforcement of such laws in the future could increase Emeras exposure to additional liabilities and costs. These changes could also affect earnings and strategy by changing the nature and timing of capital investments.
Per- and polyfluoroalkyl substances (PFAS) are man-made chemicals that are widely used in consumer products and can persist and bio-accumulate in the environment. The Company does not manufacture PFAS but because these emerging contaminants of concern are so ubiquitous in products and the environment, it may impact Emeras operations. Changes in environmental laws and regulations related to PFAS could result in new costs or obligations for investigation and cleanup and change the Companys strategy for land acquisition for projects such as solar generation.
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, Emeras business could be materially affected by changes in government policy, utility regulation, and environmental and other legislation that could occur in response to environmental and climate change concerns.
Emera manages its environmental risk by operating in a manner that is respectful and protective of the environment and in compliance with applicable legal requirements and Company policy. Emera has implemented this policy through the development and application of environmental management systems in its operating subsidiaries. Comprehensive audit programs are in place to regularly assess compliance.
CYBERSECURITY RISK
Emera is exposed to potential risks related to cyberattacks and unauthorized access. The Company relies on IT systems, cloud infrastructure, third-party service providers and the diligence of its team members to effectively manage and safely operate its assets. This includes controls for interconnected systems of generation, distribution and transmission as well as financial, billing and other enterprise systems. As the Company operates critical assets, it may be at greater risk of cyberattacks, which could include those from nation-state cyber threat actors. Major emerging and ongoing global conflicts may also elevate this risk.
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Managements Discussion & Analysis
Cyberattacks can reach the Companys assets and information via their interfaces with third parties or the public internet and gain access to critical infrastructures. Cyberattacks can also occur via personnel with access to critical assets or trusted networks. Methods used to attack critical assets could include generic or energy-sector-specific malware delivered via network transfer, removable media, attachments, or links in e-mails. The methods used by attackers are continuously evolving and can be difficult to predict and detect.
Despite security measures in place, that are described below, the Companys 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, unavailability of critical assets, safety issues, or the 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.
Cyberattacks or unauthorized accesses may cause lost revenues, costs, losses and damages all, or some of which, may not be recoverable (through insurance, legal, regulatory cost recovery or other processes). This could materially adversely affect Emeras business and financial results including its reputation 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 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 and policies derived, in part, on the National Institute of Standards and Technologys Cyber Security Framework, periodic security testing, program maturity objectives, cybersecurity incident readiness program, and employee communication and training. With respect to certain of its assets, the Company is required to comply with rules and standards relating to cybersecurity and IT including, but not limited to, those mandated by bodies such as the North American Electric Reliability Corporation, Northeast Power Coordinating Council, and the United States Department of Homeland Security. The status of key elements of the Companys cybersecurity program is reported to the RSC. The Board oversees risk and mitigation plans in relation to cybersecurity risks and receives a quarterly update in a risk dashboard at each regularly scheduled Board meeting.
PUBLIC HEALTH RISK
An outbreak of infectious disease, a pandemic or a similar public health threat, or a fear of any of the foregoing, could adversely impact the Company, including causing operating, supply chain and project development delays and disruptions, labour shortages and shutdowns (including as a result of government regulation and prevention measures), which could have a negative impact on the Companys operations.
Any adverse changes in general economic and market conditions arising as a result of a public health threat could negatively impact demand for electricity and natural gas, revenue, operating costs, timing and extent of capital expenditures, results of financing efforts, or credit risk and counterparty risk; which could result in a material adverse effect on the Companys business. The Company maintains pandemic and business contingency plans in each of its operations to manage and help mitigate the impact of any such public health threat.
ENERGY CONSUMPTION RISK
Emeras 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, weather events, customers focus on energy efficiency, changes in rates, 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 Emeras operations, rate base, net earnings, and cash flows. The Companys rate-regulated utilities are focused on understanding customer demand, energy efficiency, and government policy to ensure that the impact of these activities benefit customers, that they do not negatively impact the reliability of the energy service and that they are addressed through regulations.
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Managements Discussion & Analysis
FOREIGN EXCHANGE RISK
The Company is exposed to foreign currency exchange rate changes. Emera operates internationally, with an increasing amount of the Companys net income earned outside of Canada. As such, Emera is exposed to movements in exchange rates between the CAD and, particularly, the USD, which could positively or adversely affect results.
Consistent with the Companys risk management policies, Emera manages currency risks through matching United States denominated debt to finance its United States operations and may use foreign currency derivative instruments to hedge specific transactions and earnings exposure. The Company may enter FX forward and swap contracts to limit exposure on certain foreign currency transactions such as fuel purchases, revenue streams and capital expenditures, and on net income earned outside of Canada. The regulatory framework for the Companys rate-regulated subsidiaries permits the recovery of prudently incurred costs, including FX.
The Company does not utilize derivative financial instruments for foreign currency trading or speculative purposes or to hedge the value of its investments in foreign subsidiaries. Exchange gains and losses on net investments in foreign subsidiaries do not impact net income as they are reported in Accumulated Other Comprehensive Income (Loss) (AOCI) (AOCL).
LIQUIDITY AND CAPITAL MARKET RISK
Liquidity risk relates to Emeras ability to ensure sufficient funds are available to meet its financial obligations. Emera manages this risk by forecasting cash requirements on a continuous basis to determine whether sufficient funds are available. Liquidity and capital needs could be financed through internally generated cash flows, asset sales, short-term credit facilities, and ongoing access to capital markets. The Company reasonably expects liquidity sources to meet capital needs.
Emeras access to capital and cost of borrowing is subject to several risk factors, including financial market conditions, market disruptions and ratings assigned by various market analysts, including 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. Emeras growth plan requires significant capital investments in PP&E and the risk associated with changes in interest rates could have an adverse effect on the cost of financing. The Companys future access to capital and cost of borrowing may be impacted by various market disruptions. The inability to access cost-effective capital could have a material impact on Emeras 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 Companys business, its regulatory framework and legislative environment, political interference in the regulatory process, the ability to recover costs and earn returns, diversification, leverage, liquidity and increased exposure to climate change-related impacts, including increased frequency and severity of hurricanes and other severe weather events. A decrease in a credit rating could result in higher interest rates in future financings, increased borrowing costs under certain existing credit facilities, limit access to the commercial paper market, or limit the availability of adequate credit support for subsidiary operations. For more information on interest rate risk, refer to General Economic Risk Interest Rate Risk. For certain derivative instruments, if the credit ratings of the Company were reduced below investment grade, the full value of the net liability of these positions could be required to be posted as collateral. Emera manages these risks by actively monitoring and managing key financial metrics with the objective of sustaining investment grade credit ratings.
The Company has exposure to its own common share price through the issuance of various forms of stock-based compensation, which affect earnings through revaluation of the outstanding units every period. The Company uses equity derivatives to reduce the earnings volatility derived from stock-based compensation.
GENERAL ECONOMIC RISK
The Company has exposure to the macro-economic conditions in North America and in other geographic regions in which Emera operates. Like most utilities, economic factors such as consumer income, employment and housing affect demand for electricity and natural gas and, in turn, the Companys financial results. Adverse changes in general economic conditions and inflation may impact the ability of customers to afford rate increases arising from increases to fuel, operating, capital, environmental compliance, and other costs, and therefore could materially affect Emera and its utilities. This may also result in higher credit and counterparty risk, adverse shifts in government policy and legislation, and/or increased risk to full and timely recovery of costs and regulatory assets.
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Managements Discussion & Analysis
Interest Rate Risk:
Emera utilizes a combination of fixed and floating rate debt financing for operations and capital expenditures, resulting in an exposure to interest rate risk. Emera seeks to manage interest rate risk through a portfolio approach that includes the use of fixed and floating rate debt with staggered maturities. The Company will, from time to time, issue long-term debt or enter interest rate hedging contracts to limit its exposure to fluctuations in floating interest rate debt.
For Emeras 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 ROEs 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.
Interest rates could also be impacted by changes in credit ratings. For more information, refer to Liquidity and Capital Market Risk.
As with most other utilities and other similar yield-returning investments, Emeras share price may be affected by changes in interest rates and could underperform the market in an environment of rising interest rates.
Inflation Risk:
The Company may be exposed to changes in inflation that may result in increased operating and maintenance costs, capital investment, and fuel costs compared to the revenues provided by customer rates. Emeras utilities have budgeting and forecasting processes to identify inflationary risk factors and measure operating performance, as well as collective bargaining agreements that mitigate the short-term impact of inflation on labour costs of unionized employees.
PROJECT DEVELOPMENT AND LAND USE RIGHTS RISK
The Companys capital plan includes significant investment in generation, infrastructure modernization, and customer-focused technologies. Any projects planned or currently in construction, particularly significant capital projects, may be subject to risks including, but not limited to, impact on costs from schedule delays, increased demand for renewable energy inputs, risk of cost overruns, ensuring compliance with operating and environmental requirements and other events within or beyond the Companys control. The Companys projects may also require approvals and permits at the federal, provincial, state, regional and local levels. There is no assurance that Emera will be able to obtain the necessary project approvals or applicable permits or receive regulatory approval to recover the costs in rates.
Some of the Companys assets are located on land owned by third parties, including Indigenous Peoples, and may be subject to land claims. Present or future assets may be located on lands that have been used for traditional purposes and therefore subject to specific consultations, consents, or conditions for development or operation. If the Companys rights to locate and operate its assets on any such lands are subject to expiry or become invalid, it may incur material costs to renew rights or obtain such rights. If reasonable terms for land-use rights cannot be negotiated, the Company may incur significant costs to remove and relocate its assets and restore the land. Additional costs incurred could cause projects to be uneconomical to proceed with.
Emera manages these project development and land use rights risks by deploying robust project and risk management approaches, led by teams with extensive experience in large projects. The Company consults with Indigenous Peoples in obtaining approvals, constructing, maintaining and operating such facilities, consistent with laws and public policy frameworks. Emera maintains relationships through on-going communications with stakeholders, including Indigenous Peoples, landowners and governments.
COUNTERPARTY RISK
Emera is exposed to risk related to its reliance on certain key partners, suppliers, and customers, any of which may endure financial challenges resulting from commodity price and market volatility, economic instability or adversity, adverse political or regulatory changes and other causes which may cause or contribute to such parties insolvency, bankruptcy, restructuring or default on their contractual obligations to Emera. Emera is also exposed to potential losses related to amounts receivable from customers, energy marketing collateral deposits and derivative assets due to a counterpartys non-performance under an agreement.
EMERA 2023 ANNUAL REPORT | 53 |
Managements Discussion & Analysis
Emera manages this counterparty risk through due diligence and third-party risk assessment processes prior to signing contracts, contractual rights and remedies, regulatory frameworks, and by monitoring significant developments with its customers, partners and suppliers. The Company also manages credit risk with policies and procedures for counterparty analysis, exposure measurement, and exposure monitoring and mitigation. Credit assessments may be conducted on new customers and counterparties, and deposits or collateral may be requested on certain accounts. There is no assurance that management strategies will be effective, and significant counterparty defaults could have a material effect on the Company.
COUNTRY RISK
The majority of Emeras earnings are from outside of Canada, mostly concentrated in the United States. Emeras investments are currently in regions where political and economic risks are considered by the Company to be acceptable. For more information, refer to the Regulatory and Political Risk and General Economic Risk sections above. Emeras operations in some countries may be subject to changes in economic growth, restrictions on the repatriation of income or capital exchange controls, inflation, the effect of global health, safety and environmental matters, including climate change, or economic conditions and market conditions, and change in financial policy and availability of credit. The Company mitigates this risk through a rigorous approval process for investment, and by forecasting cash requirements on a continuous basis to determine whether sufficient funds are available in all affiliates.
SUPPLY CHAIN RISK
Emeras ability to meet customer energy requirements, respond to storm-related disruptions and execute on our capital program in a cost-effective and timely manner are dependent on maintaining an efficient supply chain. Domestic and global supply chain issues may delay the delivery or result in shortages of certain materials, equipment and other resources that are critical to the Companys operations. These disruptions may be further exacerbated by inflationary pressures, labour shortages, government incentives increasing demand for clean energy projects, and the impact of international conflicts, tariffs, or other trade restrictions. Failure to eliminate or manage supply chain constraints may impact the availability and cost of items and labour that are necessary to support operations and capital investment. Emera continues to monitor the situation and seeks to mitigate the impacts of supply chain risk by securing alternative suppliers, third party risk management, modifying design standards, and adjusting the timing of work.
COMMODITY PRICE RISK
The Companys utility fuel supply and purchase of other commodities is subject to commodity price risk. In addition, Emera Energy is subject to commodity price risk through its portfolio of commodity contracts and arrangements.
The Company manages this risk through established processes and practices to identify, monitor, report and mitigate these risks. These include the Companys commercial arrangements, such as the combination of supply and purchase agreements, asset management agreements, pipeline transportation agreements, and financial hedging instruments. In addition, its credit policies, counterparty credit assessments, market and credit position reporting, and other risk management and reporting practices, are also used to manage and mitigate this risk.
Regulated Utilities:
The Companys utility fuel supply is exposed to broader global conditions, which may include impacts on delivery reliability and price, despite contracted terms. Supply and demand dynamics in fuel markets can be affected by a wide range of factors which are difficult to predict and may change rapidly, including but not limited to, currency fluctuations, changes in global economic conditions, natural disasters, transportation or production disruptions, and geo-political risks, such as political instability, conflicts, changes to international trade agreements, trade sanctions or embargos. The Company seeks to manage this risk using financial hedging instruments and physical contracts and through contractual protection with counterparties, where applicable.
The majority of Emeras regulated electric and gas utilities have adopted and implemented fuel adjustment mechanisms and purchased gas adjustment mechanisms respectively, which further helps manage commodity price risk, as the regulatory framework for the Companys rate-regulated subsidiaries permits the recovery of prudently incurred fuel and gas costs. There is no assurance that such mechanisms and regulatory frameworks will continue to exist in the future. Prolonged and substantial increases in fuel prices could result in decreased rate affordability, increased risk of recovery of costs or regulatory assets, and/or negative impacts on customer consumption patterns and sales.
54 | EMERA 2023 ANNUAL REPORT |
Managements Discussion & Analysis
Emera Energy Marketing and Trading:
Emera Energy has employed further measures to manage commodity risk. The majority of Emera Energys 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. Changes in commodity prices can also result in increased collateral requirements associated with physical contracts and financial hedges, resulting in higher liquidity requirements and increased costs to the business.
To measure commodity price risk exposure, Emera Energy employs a number of controls and processes, including an estimated VaR analysis of its exposures. The VaR amount represents an estimate of the potential change in FV that could occur from changes in Emera Energys portfolio or changes in market factors within a given confidence level, if an instrument or portfolio is held for a specified time period. The VaR calculation is used to quantify exposure to market risk associated with physical commodities, primarily natural gas and power positions.
FUTURE EMPLOYEE BENEFIT PLAN PERFORMANCE AND FUNDING RISK
Emera subsidiaries have both defined benefit and defined contribution employee pension plans that cover their employees and retirees. All defined benefit plans are closed to new entrants, except for the TECO Energy Group Retirement Plan and the Grand Bahama Power Company Limited Union Employees Pension Plan. The cost of providing these benefit plans varies depending on plan provisions, interest rates, inflation, 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. Three of the largest drivers of cost are investment performance, interest rates and inflation, which are affected by global financial and capital markets. Depending on future interest rates and future inflation and actual versus expected investment performance, Emera could be required to make larger contributions in the future to fund these plans, which could adversely affect Emeras cash flows, financial condition and operations.
Each of Emeras 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 Companys fiduciary and financial objectives. Studies are routinely undertaken approximately every five years with the objective that the plans asset allocations are appropriate for meeting Emeras long-term pension objectives.
LABOUR RISK
Emeras 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 Companys 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 30 per cent of Emeras 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 Companys 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.
EMERA 2023 ANNUAL REPORT | 55 |
Managements Discussion & Analysis
IT RISK
Emera relies on various IT 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 IT, 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. Emeras digital transformation strategy, including investment in infrastructure modernization and customer focused technologies, is driving increased investment in IT solutions, resulting in increased project risks associated with the implementation of these solutions.
Emera manages these risks through IT asset lifecycle planning and management, governance, internal auditing and testing of systems, and executive oversight. Employees with extensive subject matter expertise assist in risk identification and mitigation, project management, implementation, change management and training. System resiliency, formal disaster recovery and backup processes, combined with critical incident response practices, table-top exercises, and simulations, help mitigate operational disruptions.
INCOME TAX RISK
The computation of the Companys 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 Companys future earnings, cash flows, and financial position. The value of Emeras existing deferred income 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 Companys 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 Emeras 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, supply chain issues impacting timely access to critical equipment, activities of third parties, terrorism, cyberattacks, damage to facilities, solar panels and infrastructure caused by hurricanes, storms, falling trees, lightning strikes, floods, fires and other natural disasters. Natural gas pipeline operations can also be impacted by risks such as leaks, explosions, mechanical failures, activities of third parties, terrorism, cyberattacks, and damage to the pipeline facilities and equipment caused by hurricanes, storms, floods, fires and other natural disasters. Refer to Global Climate Change Risk and Weather Risk. Electric utility and natural gas transmission and distribution pipeline operation interruption could negatively affect revenue, earnings, and cash flows as well as customer and public confidence, and public safety.
Emera manages these risks by investing in a highly skilled workforce, operating prudently, preventative maintenance, safety and operations management systems, third-party risk program, and making effective capital investments. Insurance, warranties, or recovery through regulatory mechanisms may not cover any or all these losses, which could adversely affect the Companys results of operations and cash flows.
Fuel Supply Disruptions:
Emeras electric and natural gas utilities are also exposed to the risk of fuel supply chain disruptions, both within and outside their service territories, which may be caused by severe weather or natural disasters. This may also be caused by damage to, operational issues with, terrorist or cyberattacks on, third party fuel production, storage, pipeline, and distribution facilities. The risk of fuel supply disruptions is managed through contractual protections, maintaining a diversity of fuel suppliers and transportation contracts, and contracting for access to third-party storage facilities. Significant unanticipated fuel supply disruptions could result in increased exposure to commodity price risk for Emeras regulated electric and gas utilities and Emera Energy, and these could have adverse effects on service to utility customers and on the Companys reputation, earnings, cash flow and financial position.
56 | EMERA 2023 ANNUAL REPORT |
Managements Discussion & Analysis
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 Emeras risk management policies. Certain facilities, in particular coal and other thermal generation, may, over time, become more difficult (or uneconomic) to insure as a result of the impact of global climate change. Refer to Global Climate Change Risk Markets. There are certain elements of Emeras operations which are not insured. These include a significant portion of its electric utilities transmission and distribution assets and its gas utilities 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 Emeras results of operations, cash flows and financial position, if regulatory recovery is not available.
The Company manages its insured risk by aligning insurance limits with risk exposures, and for uninsured assets and operations, that appropriate risk assessments and mitigation measures are in place. The regulatory framework for the Companys rate- regulated subsidiaries permits the recovery of prudently incurred costs, including uninsured losses.
Risk Management including Financial Instruments
Emeras risk management policies and procedures provide a framework through which management monitors various risk exposures. Risk management policies and practices are overseen by the Board. 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 ERMC, whose responsibilities include preparing an updated risk dashboard and heat map presented at regular meetings of the Boards Risk and Sustainability Committee. Furthermore, a corporate team independent from operations is responsible for tracking and reporting on market and credit risks.
The Company manages exposure to normal operating and market risks relating to commodity prices, FX, interest rates and share prices through contractual protections with counterparties where practicable, and by using financial instruments consisting mainly of FX 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 HFT. Collectively, these contracts and financial instruments are considered derivatives.
The Company recognizes the FV of all its derivatives on its balance sheet, except for non-financial derivatives that meet the normal purchases and normal sales (NPNS) exception. Physical contracts that meet the NPNS exception are not recognized on the balance sheet; these contracts are recognized in income when they settle. A physical contract generally qualifies for the NPNS exception if the transaction is reasonable in relation to the Companys 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 if the criteria are no longer met.
Derivatives qualify for hedge accounting if they meet stringent documentation requirements and can be proven to effectively hedge identified risk both at the inception and over the term of the instrument. Specifically, for cash flow hedges, change in the FV of derivatives is deferred to AOCI and recognized in income in the same period the related hedged item is realized. Where documentation or effectiveness requirements are not met, the derivatives are recognized at FV with any changes in FV value recognized in net income in the reporting period, unless deferred as a result of regulatory accounting.
Derivatives entered into by NSPI, NMGC and GBPC that are documented as economic hedges or for which the NPNS exception has not been taken, are subject to regulatory accounting treatment. The change in FV 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. TEC has no derivatives related to hedging as a result of a FPSC approved five-year moratorium on hedging of natural gas purchases that ended on December 31, 2022 and was extended through December 31, 2024 as a result of TECs 2021 rate case settlement agreement.
EMERA 2023 ANNUAL REPORT | 57 |
Managements Discussion & Analysis
Derivatives that do not meet any of the above criteria are designated as HFT, with changes in FV normally recorded in net income of the period. The Company has not elected to designate any derivatives to be included in the HFT category where another accounting treatment would apply.
DERIVATIVE ASSETS AND LIABILITIES RECOGNIZED ON THE BALANCE SHEET
As at millions of dollars |
December 31 2023 |
December 31 2022 |
||||||
Regulatory Deferral: |
||||||||
Derivative instrument assets (1) |
$ | 16 | $ | 238 | ||||
Derivative instrument liabilities (2) |
(76 | ) | (25 | ) | ||||
Regulatory assets (1) |
88 | 30 | ||||||
Regulatory liabilities (2) |
(17 | ) | (230 | ) | ||||
|
|
|
|
|||||
Net asset |
$ | 11 | $ | 13 | ||||
|
|
|
|
|||||
HFT Derivatives: |
||||||||
Derivative instrument assets (1) |
$ | 202 | $ | 153 | ||||
Derivatives instruments liabilities (2) |
(421 | ) | (1,025 | ) | ||||
|
|
|
|
|||||
Net liability |
$ | (219 | ) | $ | (872 | ) | ||
|
|
|
|
|||||
Other Derivatives: |
||||||||
Derivative instrument assets (1) |
$ | 22 | $ | 5 | ||||
Derivatives instruments liabilities (2) |
(7 | ) | (28 | ) | ||||
|
|
|
|
|||||
Net asset (liability) |
$ | 15 | $ | (23 | ) | |||
|
|
|
|
(1) | Current and other assets. |
(2) | Current and long-term liabilities. |
REALIZED AND UNREALIZED GAINS (LOSSES) RECOGNIZED IN NET INCOME
For the | Year ended December 31 | |||||||
millions of dollars |
2023 | 2022 | ||||||
Regulatory Deferral: |
||||||||
Regulated fuel for generation and purchased power (1) |
$ | 62 | $ | 210 | ||||
|
|
|
|
|||||
HFT Derivatives: |
||||||||
Non-regulated operating revenues |
$ | 1,037 | $ | 64 | ||||
|
|
|
|
|||||
Other Derivatives: |
||||||||
OM&G |
$ | (9 | ) | $ | (22 | ) | ||
Other income, net |
17 | (24 | ) | |||||
|
|
|
|
|||||
Net gains (losses) |
$ | 8 | $ | (46 | ) | |||
|
|
|
|
|||||
Total net gains |
$ | 1,107 | $ | 228 | ||||
|
|
|
|
(1) | Realized gains (losses) on derivative instruments settled and consumed in the period, hedging relationships that have been terminated or the hedged transaction is no longer probable. Realized gains (losses) recorded in inventory will be recognized in Regulated fuel for generation and purchased power when the hedged item is consumed. |
For the year ended December 31, 2023, unrealized gains of $2 million (2022 $2 million), have been reclassified out of AOCI into interest expense.
December 31, | December 31, | |||||||
As at |
2023 | 2022 | ||||||
millions of dollars |
Interest rate hedge |
Interest rate hedge |
||||||
Total unrealized gain in AOCI net of tax |
$ | 14 | $ | 16 | ||||
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58 | EMERA 2023 ANNUAL REPORT |
Managements Discussion & Analysis
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 Companys internal control framework is based on 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 Companys DC&P and ICFR as at December 31, 2023 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 Companys ICFR, during the year ended December 31, 2023, that have materially affected, or are reasonably likely to materially affect, the Companys internal control over financial reporting.
Critical Accounting Estimates
The preparation of consolidated financial statements in accordance with USGAAP requires management to make estimates and assumptions. These may affect reported amounts of assets and liabilities at the date of the financial statements and reported amounts of revenues and expenses during the reporting periods. Significant areas requiring use of management estimates relate to rate-regulated assets and liabilities, accumulated reserve for cost of removal, pension and post-retirement benefits, unbilled revenue, useful lives for depreciable assets, goodwill and long-lived assets impairment assessments, income taxes, asset retirement obligations (ARO), and valuation of financial instruments. Management evaluates the Companys estimates on an ongoing basis based upon historical experience, current and expected conditions and assumptions believed to be reasonable at the time the assumption is made, with any adjustments recognized in income in the year they arise.
RATE REGULATION
The rate-regulated accounting policies of Emeras rate-regulated subsidiaries and regulated equity investments are subject to examination and approval by their respective regulators and may differ from the accounting policies of non-rate-regulated companies. Differences occur when regulators render their decisions on rate applications or other matters, and generally involve a difference in the timing of revenue and expense recognition. The accounting for these items is based on expectations of the future actions of the regulators. Assumptions and judgments used by regulatory authorities continue to have an impact on recovery of costs, rates earned on invested capital, and the timing and amount of assets to be recovered. 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.
As at December 31, 2023, the Company had recorded $3,105 million (2022 $3,620 million) of regulatory assets and $1,772 million (2022 $2,273 million) of regulatory liabilities.
ACCUMULATED RESERVE COST OF REMOVAL
TEC, PGS, NMGC and NSPI recognize non-ARO costs of removal (COR) as regulatory liabilities. The non-ARO COR represent estimated funds received from customers through depreciation rates to cover future COR of PP&E upon retirement that are not legally required. The companies accrue for COR over the life of the related assets based on depreciation studies approved by their respective regulators. Costs are estimated based on historical experience and future expectations, including expected timing and estimated future cash outlays. As at December 31, 2023, the balance of the Accumulated reserve COR within regulatory liabilities was $849 million (2022 $895 million).
EMERA 2023 ANNUAL REPORT | 59 |
Managements Discussion & Analysis
PENSION AND OTHER POST-RETIREMENT EMPLOYEE BENEFITS
The Company provides post-retirement benefits to employees, including defined benefit pension plans. The cost of providing these benefits is dependent upon many factors that result from actual plan experience and assumptions of future expectations.
The accounting related to employee post-retirement benefits is a critical accounting estimate. Changes in the estimated benefit obligation, affected by employee demographics including age, compensation levels, employment periods, contribution levels and earnings could have a material impact on reported assets, liabilities, accumulated other comprehensive income and results of operations. Changes in key actuarial assumptions, including anticipated rates of return on plan assets and discount rates used in determining the accrued benefit obligation and benefit costs, could change annual funding requirements. This could have a significant impact on the Companys annual earnings and cash requirements.
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 Companys 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 8.0 years (8.4 years for 2023 benefit cost) for Canadian plans and a weighted average of 11.5 years for United States plans. The Companys use of smoothed asset values reduces volatility related to amortization of actuarial investment experience. As a result, the main cause of volatility in reported pension cost is the discount rate used to determine the PBO.
The discount rate used to determine benefit costs is based on the yield of high quality long-term corporate bonds in each operating entitys 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:
2023 | 2022 | |||||||||||||||
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 |
5.55% | 7.05% | 2.78% | 6.50% | ||||||||||||
TECO Energy Group Supplemental Executive Retirement Plan (1) |
5.45%/5.31% | N/A | 2.35/5.33% | N/A | ||||||||||||
TECO Energy Group Benefit Restoration Plan (1) |
5.48/5.30/5.49% | N/A | 2.27/4.19/5.48% | N/A | ||||||||||||
TECO Energy Post-retirement Health and Welfare Plan |
5.53%/6.14% | N/A | 2.84% | N/A | ||||||||||||
New Mexico Gas Company Retiree Medical Plan |
5.55% | 2.50% | 2.85% | 1.50% | ||||||||||||
NSPI |
5.17%, 5.19% | 6.25% | 3.25%, 3.48% | 5.75% | ||||||||||||
GBPC Salaried |
5.75% | 6.00% | 5.75% | 6.00% | ||||||||||||
GBPC Union |
5.75% | 5.35% | 5.75% | 5.35% | ||||||||||||
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(1) | The discount rate for benefit cost purposes is updated throughout the year as special events occur, such as settlements and curtailments. |
Based on managements estimate, the reported benefit cost for defined benefit and defined contribution plans was $43 million in 2023 (2022 $64 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 2023 benefit cost of $0.5 million and $2.5 million, respectively (2022 $0.5 million and $1 million).
UNBILLED REVENUE
Electric and gas revenues are billed on a systematic basis over a one or two-month period for NSPI and a one-month period for other Emera utilities. At the end of each month, the Company must make an estimate of energy delivered to customers since the date their meter was last read and determine related revenues earned but not yet billed. The unbilled revenue is estimated based on several factors, including current months generation, estimated customer usage by class, weather, line losses, inter- period changes to customer classes and applicable customer rates. Based on the extent of estimates included in determination of unbilled revenue, actual results may differ from the estimate. At December 31, 2023, unbilled revenues totalled $363 million (2022 $424 million) on total regulated operating revenues of $7,235 million (2022 $7,154 million).
60 | EMERA 2023 ANNUAL REPORT |
Managements Discussion & Analysis
PP&E
PP&E represents 62 per cent of total assets on the Companys balance sheet and includes generation, transmission and distribution, and other assets of the Company.
Depreciation is determined by the straight-line method, based on the estimated remaining service lives of depreciable assets in each category. The service lives of regulated PP&E are determined based on depreciation studies and require appropriate regulatory approval. Due to the magnitude of the Companys PP&E, changes in estimated depreciation rates can have a material impact on depreciation expense and accumulated depreciation.
Depreciation expense was $1,019 million for the year ended December 31, 2023 (2022 $927 million).
GOODWILL IMPAIRMENT ASSESSMENTS
Goodwill is calculated as the excess of the purchase price of an acquired entity over the estimated FV of identifiable assets acquired, and liabilities assumed at the acquisition date.
Goodwill is subject to assessment for impairment at the reporting unit level annually, or if an event or change in circumstances indicates that the FV of a reporting unit may be below its carrying value. Application of the goodwill impairment test requires management judgment on significant assumptions and estimates. When assessing goodwill for impairment, the Company has the option of first performing a qualitative assessment to determine whether a quantitative assessment is necessary. In performing a qualitative assessment, management considers, among other factors, macroeconomic conditions, industry and market considerations and overall financial performance.
If the Company performs a qualitative assessment and determines it is more likely than not that its FV is less than its carrying amount, or if the Company chooses to bypass the qualitative assessment, a quantitative test is performed. The quantitative test compares the FV of the reporting unit to its carrying amount, including goodwill. If the carrying amount of the reporting unit exceeds its FV, an impairment loss is recorded. Significant assumptions used in estimating the FV of a reporting unit include discount and growth rates, rate case assumptions including future cost of capital, valuation of the reporting units net operating loss (NOL), and projected operating and capital cash flows. Adverse changes in these assumptions could result in a future material impairment of the goodwill assigned to Emeras reporting units.
As of December 31, 2023, $5,868 million (2022 $6,009 million) of Emeras goodwill represents the excess of the acquisition purchase price for TECO Energy (TEC, PGS and NMGC reporting units) over the FV assigned to identifiable assets acquired and liabilities assumed. In Q4 2023, qualitative assessments were performed for NMGC and PGS, given the significant excess of FV over carrying amounts calculated during the last quantitative tests in Q4 2022 and Q4 2019, respectively. Management concluded it was more likely than not that the FV of these reporting units exceeded their respective carrying amounts, including goodwill. As such, no quantitative testing was required. Given the length of time passed since the last quantitative impairment test for the TEC reporting unit, Emera elected to bypass a qualitative assessment and performed a quantitative impairment assessment in Q4 2023 using a combination of the income and market approach. This assessment estimated that the FV of the TEC reporting unit exceeded its carrying amount, including goodwill, and as a result no impairment charges were recognized.
As of December 31, 2023, the Company had goodwill with a total carrying amount of $5,871 million (December 31, 2022
$6,012 million). The change in the carrying value of goodwill from 2022 to 2023 was a result of the effect of the FX translation of Emeras foreign affiliates.
In Q4 2022, as a result of a quantitative assessment, the Company recorded a goodwill impairment charge of $73 million, reducing the GBPC goodwill balance to nil as at December 31, 2022. For further detail, refer to note 22 in the consolidated financial statements.
LONG-LIVED ASSETS IMPAIRMENT ASSESSMENTS
The Company assesses whether there has been an impairment of long-lived assets and intangibles when a triggering event occurs, such as a significant market disruption or the sale of a business. The assessment involves comparing 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 FV.
EMERA 2023 ANNUAL REPORT | 61 |
Managements Discussion & Analysis
The Company believes accounting estimates related to asset impairments are critical estimates, as they are highly susceptible to change and the impact of an impairment on reported assets and earnings could be material. Management is required to make assumptions based on expectations regarding results of operations for significant/indefinite future periods and current and expected market conditions in such periods. Markets can experience significant uncertainties. Estimates based on the Companys 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 Companys expectations regarding uses and holding periods of assets are based on internal long-term budgets and projections, which consider external factors and market forces, as of the end of each reporting period. Assumptions made by management are consistent with generally accepted industry approaches and assumptions used for valuation and pricing activities.
As at December 31, 2023, there were no indications of impairment of Emeras long-lived assets. No impairment charges were recognized in either 2023 or 2022.
INCOME TAXES
Income taxes are determined based on 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 income tax assets will be recovered from future taxable income is assessed, and assumptions are made about expected timing of reversal of deferred income tax assets and liabilities. Uncertainty associated with application of tax statutes and regulations and outcomes of tax audits and appeals, requires that judgments and estimates be made in the accrual process and in calculation of effective tax rates. Only income tax benefits that meet the more likely than not threshold may be recognized or continue to be recognized. Unrecognized tax benefits are evaluated quarterly and changes are recorded based on new information, including issuance of relevant guidance by the courts or tax authorities and developments occurring in examinations of the Companys tax returns.
The Company believes accounting estimates related to income taxes are critical estimates. Realization of deferred income tax assets depends on the generation of sufficient taxable income, both operating and capital, in future periods. A change in estimated valuation allowance could have a material impact on reported assets and results of operations. Administrative actions of tax authorities, changes in tax law or regulation, and uncertainty associated with the application of tax statutes and regulations, could change the Companys estimate of income taxes, including the potential for elimination or reduction of the Companys ability to realize tax benefits and to utilize deferred income tax assets.
ASSET RETIREMENT OBLIGATIONS
Measurement of the FV of AROs requires the Company to make reasonable estimates concerning the method and timing of settlement associated with 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 remediation of generation, transmission, distribution and pipeline assets.
An ARO represents the FV of estimated cash flows necessary to discharge the future obligation using the Companys credit- adjusted risk-free rate. The amounts are reduced by actual expenditures incurred. Estimated future cash flows are based on completed depreciation studies, remediation reports, prior experience, estimated useful lives, and governmental regulatory requirements. The present value of the liability is recorded and the carrying amount of the related long-lived asset is correspondingly increased. The amount capitalized at inception is depreciated in the same manner as the related long-lived asset. Over time, the liability is accreted to its estimated future value. Accretion expense is included as part of Depreciation and amortization expense. Any accretion expense not yet approved by the regulator is recorded in PP&E 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.
62 | EMERA 2023 ANNUAL REPORT |
Managements Discussion & Analysis
Some of the Companys transmission and distribution assets may have conditional AROs that are not recognized in the consolidated financial statements as the FV of these obligations could not be reasonably estimated given 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 FV when an amount can be determined.
As at December 31, 2023, AROs recorded on the balance sheet were $192 million (2022 $174 million). The Company estimates the undiscounted amount of cash flow required to settle the obligations is approximately $426 million (2022 $429 million), which will be incurred between 2023 and 2061. The majority of these costs will be incurred between 2028 and 2050.
FINANCIAL INSTRUMENTS
The Company is required to determine the FV of all derivatives except those that qualify for the normal purchase, normal sale exception. FV 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. FV measurements are required to reflect assumptions that market participants would use in pricing an asset or liability based on the best available information, including the risks inherent in a particular valuation technique, such as a pricing model, and the risks inherent in the inputs to the model.
LEVEL DETERMINATIONS AND CLASSIFICATIONS
The Company uses Level 1, 2, and 3 classifications in the FV hierarchy. The FV 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 FV. FV is determined, directly or indirectly, using inputs that are observable for the asset or liability. Only in limited circumstances does the Company enter into commodity transactions involving non-standard features where market observable data is not available or have contract terms that extend beyond five years.
Changes in Accounting Policies and Practices
FUTURE ACCOUNTING PRONOUNCEMENTS
The Company considers the applicability and impact of all ASUs issued by the Financial Accounting Standards Board (FASB). The following updates have been issued by the FASB, but as allowed, have not yet been adopted by Emera. Any ASUs not included below were assessed and determined to be either not applicable to the Company or to have an insignificant impact on the consolidated financial statements.
Improvements to Income Tax Disclosures
In December 2023, the FASB issued ASU 2023-09, Income Taxes (Topic 740): Improvements to Income Tax Disclosures. The standard enhances the transparency, decision usefulness and effectiveness of income tax disclosures by requiring consistent categories and greater disaggregation of information in the reconciliation of income taxes computed using the enacted statutory income tax rate to the actual income tax provision and effective income tax rate, as well as the disaggregation of income taxes paid (refunded) by jurisdiction. The standard also requires disclosure of income (loss) before provision for income taxes and income tax expense (recovery) in accordance with U.S. Securities and Exchange Commission Regulation S-X 210.4-08(h), Rules of General Application General Notes to Financial Statements: Income Tax Expense, and the removal of disclosures no longer considered cost beneficial or relevant. The guidance will be effective for annual reporting periods beginning after December 15, 2024, and interim periods within annual reporting periods beginning after December 15, 2025. Early adoption is permitted. The standard will be applied on a prospective basis, with retrospective application permitted. The Company is currently evaluating the impact of adoption of the standard on its consolidated financial statements.
EMERA 2023 ANNUAL REPORT | 63 |
Managements Discussion & Analysis
Improvements to Reportable Segment Disclosures
In November 2023, the FASB issued ASU 2023-07, Segment Reporting (Topic 280), Improvements to Reportable Segment Disclosures. The change in the standard improves reportable segment disclosure requirements, primarily through enhanced disclosures about significant segment expenses. The changes improve financial reporting by requiring disclosure of incremental segment information on an annual and interim basis for all public entities to enable investors to develop more decision-useful financial analyses. The guidance will be effective for annual reporting periods beginning after December 15, 2023, and for interim periods beginning after December 15, 2024. Early adoption is permitted. The standard will be applied retrospectively. The Company is currently evaluating the impact of adoption of the standard on its consolidated financial statements.
Summary of Quarterly Results
For the quarter ended millions of dollars (except per share amounts) |
Q4 2023 |
Q3 2023 |
Q2 2023 |
Q1 2023 |
Q4 2022 |
Q3 2022 |
Q2 2022 |
Q1 2022 |
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Operating revenues |
$ | 1,972 | $ | 1,740 | $ | 1,418 | $ | 2,433 | $ | 2,358 | $ | 1,835 | $ | 1,380 | $ | 2,015 | ||||||||||||||||
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Net income (loss) attributable to common shareholders |
$ | 289 | $ | 101 | $ | 28 | $ | 560 | $ | 483 | $ | 167 | $ | (67 | ) | $ | 362 | |||||||||||||||
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Adjusted net income |
$ | 175 | $ | 204 | $ | 162 | $ | 268 | $ | 249 | $ | 203 | $ | 156 | $ | 242 | ||||||||||||||||
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EPS basic |
$ | 1.04 | $ | 0.37 | $ | 0.10 | $ | 2.07 | $ | 1.80 | $ | 0.63 | $ | (0.25 | ) | $ | 1.38 | |||||||||||||||
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EPS diluted |
$ | 1.04 | $ | 0.37 | $ | 0.10 | $ | 2.07 | $ | 1.80 | $ | 0.63 | $ | (0.25 | ) | $ | 1.38 | |||||||||||||||
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Adjusted EPS basic |
$ | 0.63 | $ | 0.75 | $ | 0.60 | $ | 0.99 | $ | 0.93 | $ | 0.76 | $ | 0.59 | $ | 0.92 | ||||||||||||||||
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Quarterly operating revenues and adjusted net income are affected by seasonality. The first quarter provides strong earnings contributions due to a significant portion of the Companys operations being in northeastern North America, where winter is the peak electricity usage season. The third quarter provides strong earnings contributions due to summer being the heaviest electric consumption season in Florida. Seasonal and other weather patterns, as well as the number and severity of storms, can affect demand for energy and the cost of service. Quarterly results could also be affected by items outlined in the Significant Items Affecting Earnings section.
64 | EMERA 2023 ANNUAL REPORT |
Management Report
Managements Responsibility for Financial Reporting
The accompanying consolidated financial statements of Emera Incorporated and the information in this annual report are the responsibility of management and have been approved by the Board of Directors (Board).
The consolidated financial statements have been prepared by management in accordance with United States Generally Accepted Accounting Principles. When alternative accounting methods exist, management has chosen those it considers most appropriate in the circumstances. In preparation of these consolidated financial statements, estimates are sometimes necessary when transactions affecting the current accounting period cannot be finalized with certainty until future periods. Management represents that such estimates, which have been properly reflected in the accompanying consolidated financial statements, are based on careful judgments and are within reasonable limits of materiality. Management has determined such amounts on a reasonable basis in order to ensure that the consolidated financial statements are presented fairly in all material respects. Management has prepared the financial information presented elsewhere in the annual report and has ensured that it is consistent with that in the consolidated financial statements.
Emera Incorporated maintains effective systems of internal accounting and administrative controls, consistent with reasonable cost. Such systems are designed to provide reasonable assurance that the financial information is reliable and accurate, and that Emera Incorporateds 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 26, 2024
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Scott Balfour | Gregory Blunden | |||
President and Chief Executive Officer | Chief Financial Officer |
EMERA 2023 ANNUAL REPORT | 65 |
Independent Auditors 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, 2023 and 2022, 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, 2023 and 2022, 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 Auditors responsibilities for the audit of the consolidated financial statements section of our report. We are independent of the Company in accordance with the ethical requirements that are relevant to our audit of the consolidated financial statements in Canada, and we have fulfilled our other ethical responsibilities in accordance with these requirements. We believe that the audit evidence we have obtained is sufficient and appropriate to provide a basis for our opinion.
Key audit matters
Key audit matters are those matters that, in our professional judgment, were of most significance in the audit of the consolidated financial statements of the current period. These matters were addressed in the context of the audit of the consolidated financial statements as a whole, and in forming the auditors opinion thereon, and we do not provide a separate opinion on these matters. For each matter below, our description of how our audit addressed the matter is provided in that context.
We have fulfilled the responsibilities described in the Auditors responsibilities for the audit of the consolidated financial statements section of our report, including in relation to these matters. Accordingly, our audit included the performance of procedures designed to respond to our assessment of the risks of material misstatement of the consolidated financial statements. The results of our audit procedures, including the procedures performed to address the matters below, provide the basis for our audit opinion on the accompanying consolidated financial statements.
Accounting for the effects of rate regulation | ||
Key Audit Matter | As disclosed in note 6 of the consolidated financial statements, the Company has $3.1 billion in regulatory assets and $1.8 billion in regulatory liabilities. The Companys rate-regulated subsidiaries are subject to regulation by various federal, state and provincial regulatory authorities in the geographic regions in which they operate. The regulatory rates are designed to recover the prudently incurred costs of providing the regulated products or services and provide a reasonable return on the equity invested or assets, as applicable. In addition to regulatory assets and liabilities, rate regulation impacts multiple financial statement line items, including, but not limited to, property, plant and equipment (PP&E), operating revenues and expenses, income taxes, and depreciation expense.
Auditing the impact of rate regulation on the Companys financial statements is complex and highly judgmental due to the significant judgments made by the Company to support its accounting and disclosure for regulatory matters when final regulatory decisions or orders have not yet been obtained or when regulatory formulas are complex. There is also subjectivity involved in assessing the potential impact of future regulatory decisions on the financial statements. Although the Company expects to recover costs from customers through rates, there is a risk that the regulator will not approve full recovery of the costs incurred. The Companys judgments include making an assessment of the probability of recovery of and return on costs incurred, of the potential disallowance of part of the cost incurred, or of the probable refund to customers of gains or amounts previously collected from customers through future rates. |
66 | EMERA 2023 ANNUAL REPORT |
Independent Auditors Report
Accounting for the effects of rate regulation | ||
How Our Audit Addressed the Key Audit Matter | We performed audit procedures that included, amongst others, assessing the Companys evaluation of the probability of future recovery for regulatory assets, PP&E, and refund of regulatory liabilities by obtaining and reviewing relevant regulatory orders, filings, testimony, hearings and correspondence, and other publicly available information. For regulatory matters for which regulatory decisions or orders have not yet been obtained, we inspected the rate-regulated subsidiaries filings for any evidence that might contradict the Companys assertions, and reviewed other regulatory orders, filings and correspondence for other entities within the same or similar jurisdictions to assess the likelihood of recovery or refund in future rates based on the regulators treatment of similar costs under similar circumstances. We obtained and evaluated an analysis from the Company and corroborated that analysis with letters from legal counsel, when appropriate, regarding cost recoveries, gains or amounts previously collected from customers or future changes in rates. We also assessed the methodology, accuracy and completeness of the Companys calculations of regulatory asset and liability balances based on provisions and formulas outlined in rate orders and other correspondence with the regulators. We evaluated the Companys disclosures related to the impacts of rate regulation. | |
Fair value (FV) measurement of derivative financial instruments | ||
Key Audit Matter | Held-for-trading (HFT) derivative assets of $348 million and liabilities of $567 million, disclosed in note 15 to the consolidated financial statements, are measured at FV. The Company recognized $1,037 million in realized and unrealized gains during the year with respect to HFT derivatives.
Auditing the Companys valuation of HFT derivatives is complex and highly judgmental due to the complexity of the contract terms and valuation models, and the significant estimation required in determining the FV of the contracts. In determining the FV of HFT derivatives, significant assumptions about future economic and market assumptions with uncertain outcomes are used, including third-party sourced forward commodity pricing curves based on illiquid markets, internally developed correlation factors and basis differentials. These assumptions have a significant impact on the FV of the HFT derivatives. | |
How Our Audit Addressed the Key Audit Matter | We performed audit procedures that included, amongst others, reviewing executed contracts and agreements for the identification of inputs and assumptions impacting the valuation of derivatives. With the support of our valuation specialists, we assessed the methodology and mathematical accuracy of the Companys valuation models and compared the commodity pricing curves used by the Company to current market and economic data. For the forward commodity pricing curves, we compared the Companys pricing curves to independently sourced pricing curves. We also assessed the methodology and mathematical accuracy of the Companys calculations to develop correlation factors and basis differentials. In addition, we assessed whether the FV hierarchy disclosures in note 16 to the consolidated financial statements were consistent with the source of the significant inputs and assumptions used in determining the FV of derivatives. |
Other information
Management is responsible for the other information. The other information comprises:
| Managements Discussion and Analysis |
| The information, other than the consolidated financial statements and our auditors reports thereon, in the Annual Report |
Our opinion on the consolidated financial statements does not cover the other information and we do not express any form of assurance conclusion thereon.
In connection with our audit of the consolidated financial statements, our responsibility is to read the other information, and in doing so, consider whether the other information is materially inconsistent with the consolidated financial statements or our knowledge obtained in the audit or otherwise appears to be materially misstated.
EMERA 2023 ANNUAL REPORT | 67 |
Independent Auditors Report
We obtained Managements Discussion & Analysis prior to the date of this auditors 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 auditors 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 Companys 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 Companys financial reporting process.
Auditors 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 auditors 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 Companys 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 managements 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 Companys ability to continue as a going concern. If we conclude that a material uncertainty exists, we are required to draw attention in our auditors 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 auditors 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. |
68 | EMERA 2023 ANNUAL REPORT |
Independent Auditors Report
We communicate with those charged with governance regarding, among other matters, the planned scope and timing of the audit and significant audit findings, including any significant deficiencies in internal control that we identify during our audit.
We also provide those charged with governance with a statement that we have complied with relevant ethical requirements regarding independence, and to communicate with them all relationships and other matters that may reasonably be thought to bear on our independence, and where applicable, related safeguards.
From the matters communicated with those charged with governance, we determine those matters that were of most significance in the audit of the consolidated financial statements of the current period and are therefore the key audit matters. We describe these matters in our auditors report unless law or regulation precludes public disclosure about the matter or when, in extremely rare circumstances, we determine that a matter should not be communicated in our report because the adverse consequences of doing so would reasonably be expected to outweigh the public interest benefits of such communication.
The engagement partner on the audit resulting in this independent auditors report is Tracy Brennan.
Chartered Professional Accountants
Halifax, Canada
February 26, 2024
EMERA 2023 ANNUAL REPORT | 69 |
Report of Independent Registered Public Accounting Firm
To the Shareholders and the Board of Directors of Emera Incorporated
Opinion on the Consolidated Financial Statements
We have audited the accompanying Consolidated Balance Sheets of Emera Incorporated (the Company) as of December 31, 2023 and 2022, the related Consolidated Statements of Income, Consolidated Statements of Comprehensive Income, Consolidated Statements of Changes in Equity and Consolidated Statements of Cash Flows for the years then ended, and the related notes (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, 2023 and 2022, and the consolidated results of its operations and its consolidated cash flows for each of the two years in the period ended December 31, 2023, in conformity with United States generally accepted accounting principles.
Basis for Opinion
These consolidated financial statements are the responsibility of the Companys management. Our responsibility is to express an opinion on the Companys consolidated financial statements based on our audits. We are a public accounting firm registered with the Public Company Accounting Oversight Board (United States) (PCAOB) and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.
We conducted our audits in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audits to obtain reasonable assurance about whether the consolidated financial statements are free of material misstatement, whether due to error or fraud. The Company is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. As part of our audits we are required to obtain an understanding of internal control over financial reporting but not for the purpose of expressing an opinion on the effectiveness of the Companys internal control over financial reporting. Accordingly, we express no such opinion.
Our audits included performing procedures to assess the risks of material misstatement of the consolidated financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the consolidated financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the consolidated financial statements. We believe that our audits provide a reasonable basis for our opinion.
70 | EMERA 2023 ANNUAL REPORT |
Report of Independent Registered Public Accounting Firm
Critical Audit Matters
The critical audit matters communicated below are matters arising from the current period audit of the financial statements that were communicated or required to be communicated to the audit committee and that: (1) relate to accounts or disclosures that are material to the financial statements and (2) involved our especially challenging, subjective or complex judgments. The communication of critical audit matters does not alter in any way our opinion on the consolidated financial statements, taken as a whole, and we are not, by communicating the critical audit matters below, providing separate opinions on the critical audit matters or on the accounts or disclosures to which they relate.
Accounting for the effects of rate regulation | ||
Description of the Matter | As disclosed in note 6 of the consolidated financial statements, the Company has $3.1 billion in regulatory assets and $1.8 billion in regulatory liabilities. The Companys rate-regulated subsidiaries are subject to regulation by various federal, state and provincial regulatory authorities in the geographic regions in which they operate. The regulatory rates are designed to recover the prudently incurred costs of providing the regulated products or services and provide a reasonable return on the equity invested or assets, as applicable. In addition to regulatory assets and liabilities, rate regulation impacts multiple financial statement line items, including, but not limited to, PP&E, operating revenues and expenses, income taxes, and depreciation expense.
Auditing the impact of rate regulation on the Companys financial statements is complex and highly judgmental due to the significant judgments made by the Company to support its accounting and disclosure for regulatory matters when final regulatory decisions or orders have not yet been obtained or when regulatory formulas are complex. There is also subjectivity involved in assessing the potential impact of future regulatory decisions on the financial statements. Although the Company expects to recover costs from customers through rates, there is a risk that the regulator will not approve full recovery of the costs incurred. The Companys judgments include making an assessment of the probability of recovery of and return on costs incurred, of the potential disallowance of part of the cost incurred, or of the probable refund of gains or amounts previously collected from customers through future rates. | |
How We Addressed the Matter in Our Audit | We performed audit procedures that included, amongst others, assessing the Companys evaluation of the probability of future recovery for regulatory assets, PP&E, and refund of regulatory liabilities by obtaining and reviewing relevant regulatory orders, filings, testimony, hearings and correspondence, and other publicly available information. For regulatory matters for which regulatory decisions or orders have not yet been obtained, we inspected the rate-regulated subsidiaries filings for any evidence that might contradict the Companys assertions, and reviewed other regulatory orders, filings and correspondence for other entities within the same or similar jurisdictions to assess the likelihood of recovery or refund in future rates based on the regulators treatment of similar costs under similar circumstances. We obtained and evaluated an analysis from the Company and corroborated that analysis with letters from legal counsel, when appropriate, regarding cost recoveries, gains or amounts previously collected from customers or future changes in rates. We also assessed the methodology, accuracy and completeness of the Companys calculations of regulatory asset and liability balances based on provisions and formulas outlined in rate orders and other correspondence with the regulators. We evaluated the Companys disclosures related to the impacts of rate regulation. |
EMERA 2023 ANNUAL REPORT | 71 |
Report of Independent Registered Public Accounting Firm
FV measurement of derivative financial instruments | ||
Description of the Matter | HFT derivative assets of $348 million and liabilities of $567 million, disclosed in note 15 to the consolidated financial statements, are measured at FV. The Company recognized $1,037 million in realized and unrealized gains during the year with respect to HFT derivatives.
Auditing the Companys valuation of HFT derivatives is complex and highly judgmental due to the complexity of the contract terms and valuation models, and the significant estimation required in determining the FV of the contracts. In determining the FV of HFT derivatives, significant assumptions about future economic and market assumptions with uncertain outcomes are used, including third-party sourced forward commodity pricing curves based on illiquid markets, internally developed correlation factors and basis differentials. These assumptions have a significant impact on the FV of the HFT derivatives. | |
How We Addressed the Matter in Our Audit | We performed audit procedures that included, amongst others, reviewing executed contracts and agreements for the identification of inputs and assumptions impacting the valuation of derivatives. With the support of our valuation specialists, we assessed the methodology and mathematical accuracy of the Companys valuation models and compared the commodity pricing curves used by the Company to current market and economic data. For the forward commodity pricing curves, we compared the Companys pricing curves to independently sourced pricing curves. We also assessed the methodology and mathematical accuracy of the Companys calculations to develop correlation factors and basis differentials. In addition, we assessed whether the FV hierarchy disclosures in note 16 to the consolidated financial statements were consistent with the source of the significant inputs and assumptions used in determining the FV of derivatives. |
Chartered Professional Accountants
We have served as the Companys auditor since 1998.
Halifax, Canada
February 26, 2024
72 | EMERA 2023 ANNUAL REPORT |
Consolidated Financial Statements
Emera Incorporated
Consolidated Statements of Income
For the | Year ended December 31 | |||||||
millions of dollars (except per share amounts) |
2023 | 2022 | ||||||
Operating revenues |
||||||||
Regulated electric |
$ | 5,746 | $ | 5,473 | ||||
Regulated gas |
1,489 | 1,681 | ||||||
Non-regulated |
328 | 434 | ||||||
|
|
|
|
|||||
Total operating revenues (note 5) |
7,563 | 7,588 | ||||||
|
|
|
|
|||||
Operating expenses |
||||||||
Regulated fuel for generation and purchased power |
1,881 | 2,171 | ||||||
Regulated cost of natural gas |
527 | 800 | ||||||
Operating, maintenance and general expenses (OM&G) |
1,879 | 1,596 | ||||||
Provincial, state, and municipal taxes |
433 | 367 | ||||||
Depreciation and amortization |
1,049 | 952 | ||||||
GBPC Impairment charge (note 22) |
| 73 | ||||||
|
|
|
|
|||||
Total operating expenses |
5,769 | 5,959 | ||||||
|
|
|
|
|||||
Income from operations |
1,794 | 1,629 | ||||||
|
|
|
|
|||||
Income from equity investments (note 7) |
146 | 129 | ||||||
Other income, net (note 8) |
158 | 145 | ||||||
Interest expense, net (note 9) |
925 | 709 | ||||||
|
|
|
|
|||||
Income before provision for income taxes |
1,173 | 1,194 | ||||||
|
|
|
|
|||||
Income tax expense (note 10) |
128 | 185 | ||||||
|
|
|
|
|||||
Net income |
1,045 | 1,009 | ||||||
|
|
|
|
|||||
Non-controlling interest in subsidiaries |
1 | 1 | ||||||
Preferred stock dividends |
66 | 63 | ||||||
|
|
|
|
|||||
Net income attributable to common shareholders |
$ | 978 | $ | 945 | ||||
|
|
|
|
|||||
Weighted average shares of common stock outstanding (in millions) (note 12) |
||||||||
Basic |
274 | 266 | ||||||
Diluted |
274 | 266 | ||||||
|
|
|
|
|||||
Earnings per common share (note 12) |
||||||||
Basic |
$ | 3.57 | $ | 3.56 | ||||
Diluted |
$ | 3.57 | $ | 3.55 | ||||
|
|
|
|
|||||
Dividends per common share declared |
$ | 2.7875 | $ | 2.6775 | ||||
|
|
|
|
The accompanying notes are an integral part of these consolidated financial statements.
EMERA 2023 ANNUAL REPORT | 73 |
Consolidated Financial Statements
Emera Incorporated
Consolidated Statements of Comprehensive Income
For the | Year ended December 31 | |||||||
millions of dollars |
2023 | 2022 | ||||||
Net income |
$ | 1,045 | $ | 1,009 | ||||
|
|
|
|
|||||
Other comprehensive (loss) income, net of tax |
||||||||
Foreign currency translation adjustment (1) |
(270 | ) | 629 | |||||
Unrealized gains (losses) on net investment hedges (2) (3) |
38 | (97 | ) | |||||
Cash flow hedges reclassification adjustment for gains included in income (4) |
(2 | ) | (2 | ) | ||||
Unrealized losses on available-for-sale investment |
| (1 | ) | |||||
Net change in unrecognized pension and post-retirement benefit obligation (5) |
(39 | ) | 24 | |||||
|
|
|
|
|||||
Other comprehensive (loss) income (6) |
(273 | ) | 553 | |||||
|
|
|
|
|||||
Comprehensive income |
772 | 1,562 | ||||||
|
|
|
|
|||||
Comprehensive income attributable to non-controlling interest |
1 | 1 | ||||||
|
|
|
|
|||||
Comprehensive Income of Emera Incorporated |
$ | 771 | $ | 1,561 | ||||
|
|
|
|
The accompanying notes are an integral part of these consolidated financial statements.
(1) | Net of tax recovery of $7 million for the year ended December 31, 2023 (2022 $7 million expense). |
(2) | The Company has designated $1.2 billion United States dollar (USD) denominated Hybrid Notes as a hedge of the foreign currency exposure of its net investment in USD denominated operations. |
(3) | Net of tax expense of nil for the year ended December 31, 2023 (2022 $6 million recovery). |
(4) | Net of tax expense of nil for the year ended December 31, 2023 (2022 $1 million recovery). |
(5) | Net of tax expense of $1 million for the year ended December 31, 2023 (2022 $1 million expense). |
(6) | Net of tax recovery of $6 million for the year ended December 31, 2023 (2022 $1 million expense). |
74 | EMERA 2023 ANNUAL REPORT |
Consolidated Financial Statements
Emera Incorporated
Consolidated Balance Sheets
As at | December 31 | December 31 | ||||||
millions of dollars |
2023 | 2022 | ||||||
Assets |
||||||||
Current assets |
||||||||
Cash and cash equivalents |
$ | 567 | $ | 310 | ||||
Restricted cash (note 32) |
21 | 22 | ||||||
Inventory (note 14) |
790 | 769 | ||||||
Derivative instruments (notes 15 and 16) |
174 | 296 | ||||||
Regulatory assets (note 6) |
339 | 602 | ||||||
Receivables and other current assets (note 18) |
1,817 | 2,897 | ||||||
|
|
|
|
|||||
3,708 | 4,896 | |||||||
|
|
|
|
|||||
Property, plant and equipment (PP&E), net of accumulated depreciation and amortization of $9,994 and $9,574, respectively (note 20) |
24,376 | 22,996 | ||||||
|
|
|
|
|||||
Other assets |
||||||||
Deferred income taxes (note 10) |
208 | 237 | ||||||
Derivative instruments (notes 15 and 16) |
66 | 100 | ||||||
Regulatory assets (note 6) |
2,766 | 3,018 | ||||||
Net investment in direct finance and sales type leases (note 19) |
621 | 604 | ||||||
Investments subject to significant influence (note 7) |
1,402 | 1,418 | ||||||
Goodwill (note 22) |
5,871 | 6,012 | ||||||
Other long-term assets (note 32) |
462 | 461 | ||||||
|
|
|
|
|||||
11,396 | 11,850 | |||||||
|
|
|
|
|||||
Total assets |
$ | 39,480 | $ | 39,742 | ||||
|
|
|
|
The accompanying notes are an integral part of these consolidated financial statements.
EMERA 2023 ANNUAL REPORT | 75 |
Consolidated Financial Statements
Emera Incorporated
Consolidated Balance Sheets (continued)
As at millions of dollars |
December 31 2023 |
December 31 2022 |
||||||
Liabilities and Equity |
||||||||
Current liabilities |
||||||||
Short-term debt (note 23) |
$ | 1,433 | $ | 2,726 | ||||
Current portion of long-term debt (note 25) |
676 | 574 | ||||||
Accounts payable |
1,454 | 2,025 | ||||||
Derivative instruments (notes 15 and 16) |
386 | 888 | ||||||
Regulatory liabilities (note 6) |
168 | 495 | ||||||
Other current liabilities (note 24) |
427 | 579 | ||||||
|
|
|
|
|||||
4,544 | 7,287 | |||||||
|
|
|
|
|||||
Long-term liabilities |
||||||||
Long-term debt (note 25) |
17,689 | 15,744 | ||||||
Deferred income taxes (note 10) |
2,352 | 2,196 | ||||||
Derivative instruments (notes 15 and 16) |
118 | 190 | ||||||
Regulatory liabilities (note 6) |
1,604 | 1,778 | ||||||
Pension and post-retirement liabilities (note 21) |
265 | 281 | ||||||
Other long-term liabilities (notes 7 and 26) |
820 | 825 | ||||||
|
|
|
|
|||||
22,848 | 21,014 | |||||||
|
|
|
|
|||||
Equity |
||||||||
Common stock (note 11) |
8,462 | 7,762 | ||||||
Cumulative preferred stock (note 28) |
1,422 | 1,422 | ||||||
Contributed surplus |
82 | 81 | ||||||
Accumulated other comprehensive income (AOCI) (note 13) |
305 | 578 | ||||||
Retained earnings |
1,803 | 1,584 | ||||||
|
|
|
|
|||||
Total Emera Incorporated equity |
12,074 | 11,427 | ||||||
Non-controlling interest in subsidiaries (note 29) |
14 | 14 | ||||||
|
|
|
|
|||||
Total equity |
12,088 | 11,441 | ||||||
|
|
|
|
|||||
Total liabilities and equity |
$ | 39,480 | $ | 39,742 | ||||
|
|
|
|
Commitments and contingencies (note 27)
The accompanying notes are an integral part of these consolidated financial statements.
Approved on behalf of the Board of Directors
![]() |
![]() | |
M. Jacqueline Sheppard | Scott Balfour | |
Chair of the Board | President and Chief Executive Officer |
76 | EMERA 2023 ANNUAL REPORT |
Consolidated Financial Statements
Emera Incorporated
Consolidated Statements of Cash Flows
For the | Year ended December 31 | |||||||
millions of dollars |
2023 | 2022 | ||||||
Operating activities |
||||||||
Net income |
$ | 1,045 | $ | 1,009 | ||||
Adjustments to reconcile net income to net cash provided by operating activities: |
||||||||
Depreciation and amortization |
1,060 | 959 | ||||||
Income from equity investments, net of dividends |
(22 | ) | (61 | ) | ||||
Allowance for funds used during construction (AFUDC) equity |
(38 | ) | (52 | ) | ||||
Deferred income taxes, net |
97 | 152 | ||||||
Net change in pension and post-retirement liabilities |
(68 | ) | (48 | ) | ||||
NSPI Fuel adjustment mechanism (FAM) |
(88 | ) | (162 | ) | ||||
Net change in Fair Value (FV) of derivative instruments |
(666 | ) | 206 | |||||
Net change in regulatory assets and liabilities |
554 | (471 | ) | |||||
Net change in capitalized transportation capacity |
434 | (445 | ) | |||||
GBPC impairment charge |
| 73 | ||||||
Other operating activities, net |
28 | (13 | ) | |||||
Changes in non-cash working capital (note 30) |
(95 | ) | (234 | ) | ||||
|
|
|
|
|||||
Net cash provided by operating activities |
2,241 | 913 | ||||||
|
|
|
|
|||||
Investing activities |
||||||||
Additions to PP&E |
(2,937 | ) | (2,596 | ) | ||||
Other investing activities |
20 | 27 | ||||||
|
|
|
|
|||||
Net cash used in investing activities |
(2,917 | ) | (2,569 | ) | ||||
|
|
|
|
|||||
Financing activities |
||||||||
Change in short-term debt, net |
(66 | ) | 1,028 | |||||
Proceeds from short-term debt with maturities greater than 90 days |
548 | 544 | ||||||
Repayment of short-term debt with maturities greater than 90 days |
(1,086 | ) | (680 | ) | ||||
Proceeds from long-term debt, net of issuance costs |
1,932 | 784 | ||||||
Retirement of long-term debt |
(151 | ) | (367 | ) | ||||
Net (repayments) proceeds under committed credit facilities |
(96 | ) | 511 | |||||
Issuance of common stock, net of issuance costs |
424 | 277 | ||||||
Dividends on common stock |
(488 | ) | (472 | ) | ||||
Dividends on preferred stock |
(66 | ) | (63 | ) | ||||
Other financing activities |
(12 | ) | (7 | ) | ||||
|
|
|
|
|||||
Net cash provided by financing activities |
939 | 1,555 | ||||||
|
|
|
|
|||||
Effect of exchange rate changes on cash, cash equivalents, and restricted cash |
(7 | ) | 16 | |||||
|
|
|
|
|||||
Net increase (decrease) in cash, cash equivalents, and restricted cash |
256 | (85 | ) | |||||
Cash, cash equivalents, and restricted cash, beginning of year |
332 | 417 | ||||||
|
|
|
|
|||||
Cash, cash equivalents, and restricted cash, end of year |
$ | 588 | $ | 332 | ||||
|
|
|
|
|||||
Cash, cash equivalents, and restricted cash consists of: |
||||||||
Cash |
$ | 559 | $ | 302 | ||||
Short-term investments |
8 | 8 | ||||||
Restricted cash |
21 | 22 | ||||||
|
|
|
|
|||||
Cash, cash equivalents, and restricted cash |
$ | 588 | $ | 332 | ||||
|
|
|
|
Supplementary Information to Consolidated Statements of Cash Flows (note 30)
The accompanying notes are an integral part of these consolidated financial statements.
EMERA 2023 ANNUAL REPORT | 77 |
Consolidated Financial Statements
Emera Incorporated
Consolidated Statements of Changes in Equity
Common Stock |
Preferred Stock |
Contributed Surplus |
AOCI | Retained Earnings |
Non- Controlling Interest |
Total Equity | ||||||||||||||||||||||
millions of dollars |
||||||||||||||||||||||||||||
Balance, December 31, 2022 |
$ | 7,762 | $ | 1,422 | $ | 81 | $ | 578 | $ | 1,584 | $ | 14 | $ | 11,441 | ||||||||||||||
Net income of Emera Inc. |
| | | | 1,044 | 1 | 1,045 | |||||||||||||||||||||
Other comprehensive loss, net of tax recovery of $6 million |
| | | (273 | ) | | | (273 | ) | |||||||||||||||||||
Dividends declared on preferred stock (note 28) |
| | | | (66 | ) | | (66 | ) | |||||||||||||||||||
Dividends declared on common stock ($2.7875/share) |
| | | | (759 | ) | | (759 | ) | |||||||||||||||||||
Issued under the at-the-market program (ATM), net of after-tax issuance costs |
397 | | | | | | 397 | |||||||||||||||||||||
Issued under the Dividend Reinvestment Program (DRIP), net of discount |
272 | | | | | | 272 | |||||||||||||||||||||
Senior management stock options exercised and Employee Common Share Purchase Plan (ECSPP) |
31 | | 1 | | | | 32 | |||||||||||||||||||||
Other |
| | | | | (1 | ) | (1 | ) | |||||||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||||||
Balance, December 31, 2023 |
$ | 8,462 | $ | 1,422 | $ | 82 | $ | 305 | $ | 1,803 | $ | 14 | $ | 12,088 | ||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||||||
Balance, December 31, 2021 |
$ | 7,242 | $ | 1,422 | $ | 79 | $ | 25 | $ | 1,348 | $ | 34 | $ | 10,150 | ||||||||||||||
Net income of Emera Inc. |
| | | | 1,008 | 1 | 1,009 | |||||||||||||||||||||
Other comprehensive income, net of tax expense of $1 million |
| | | 553 | | | 553 | |||||||||||||||||||||
Dividends declared on preferred stock (note 28) |
| | | | (63 | ) | | (63 | ) | |||||||||||||||||||
Dividends declared on common stock ($2.6775/share) |
| | | | (709 | ) | | (709 | ) | |||||||||||||||||||
Issued under the ATM, net of after-tax issuance costs |
248 | | | | | | 248 | |||||||||||||||||||||
Issued under the DRIP, net of discount |
238 | | | | | | 238 | |||||||||||||||||||||
Senior management stock options exercised and ECSPP |
34 | | 2 | | | | 36 | |||||||||||||||||||||
Disposal of non-controlling interest of Dominica Electricity Services Ltd (Domlec) |
| | | | | (20 | ) | (20 | ) | |||||||||||||||||||
Other |
| | | | | (1 | ) | (1 | ) | |||||||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||||||
Balance, December 31, 2022 |
$ | 7,762 | $ | 1,422 | $ | 81 | $ | 578 | $ | 1,584 | $ | 14 | $ | 11,441 | ||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
The accompanying notes are an integral part of these consolidated financial statements.
78 | EMERA 2023 ANNUAL REPORT |
Emera Incorporated
Notes to the Consolidated Financial Statements
As at December 31, 2023 and 2022
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, 2023, Emeras reportable segments include the following:
| Florida Electric Utility, which consists of Tampa Electric (TEC), a vertically integrated regulated electric utility, serving approximately 840,000 customers in West Central Florida; |
| Canadian Electric Utilities, which includes: |
| Nova Scotia Power Inc. (NSPI), a vertically integrated regulated electric utility and the primary electricity supplier in Nova Scotia, serving approximately 549,000 customers; and |
| Emera Newfoundland & Labrador Holdings Inc. (ENL), consisting of two transmission investments related to an 824 megawatt (MW) hydroelectric generating facility at Muskrat Falls on the Lower Churchill River in Labrador, developed by Nalcor Energy. ENLs two investments are: |
| a 100 per cent equity interest in NSP Maritime Link Inc. (NSPML), which developed the Maritime Link Project, a $1.8 billion transmission project, including AFUDC; and |
| a 31 per cent equity interest in the partnership capital of Labrador-Island Link Limited Partnership (LIL), a $3.7 billion electricity transmission project in Newfoundland and Labrador. |
| Gas Utilities and Infrastructure, which includes: |
| Peoples Gas System Inc. (PGS), a regulated gas distribution utility, serving approximately 490,000 customers across Florida. Effective January 1, 2023, Peoples Gas System ceased to be a division of Tampa Electric Company and the gas utility was reorganized, resulting in a separate legal entity called Peoples Gas System Inc., a wholly owned direct subsidiary of TECO Gas Operations, Inc.; |
| New Mexico Gas Company, Inc. (NMGC), a regulated gas distribution utility, serving approximately 540,000 customers in New Mexico; |
| Emera Brunswick Pipeline Company Limited (Brunswick Pipeline), a 145-kilometre pipeline delivering re-gasified liquefied natural gas from Saint John, New Brunswick to the United States border under a 25-year firm service agreement with Repsol Energy North America Canada Partnership (Repsol Energy), which expires in 2034; |
| SeaCoast Gas Transmission, LLC (SeaCoast), a regulated intrastate natural gas transmission company offering services in Florida; and |
| a 12.9 per cent equity interest in Maritimes & Northeast Pipeline (M&NP), a 1,400-kilometre pipeline that transports natural gas throughout markets in Atlantic Canada and the northeastern United States. |
| Other Electric Utilities, which includes Emera (Caribbean) Incorporated (ECI), a holding company with regulated electric utilities that include: |
| The Barbados Light & Power Company Limited (BLPC), a vertically integrated regulated electric utility on the island of Barbados, serving approximately 134,000 customers; |
| Grand Bahama Power Company Limited (GBPC), a vertically integrated regulated electric utility on Grand Bahama Island, serving approximately 19,000 customers; and |
| a 19.5 per cent equity interest in St. Lucia Electricity Services Limited (Lucelec), a vertically integrated regulated electric utility on the island of St. Lucia. |
EMERA 2023 ANNUAL REPORT | 79 |
Notes to the Consolidated Financial Statements
| Emeras other reportable segment includes investments in energy-related non-regulated companies which include: |
| Emera Energy, which consists of: |
| Emera Energy Services (EES), a physical energy business that purchases and sells natural gas and electricity and provides related energy asset management services; |
| Brooklyn Power Corporation (Brooklyn Energy), a 30 MW biomass co-generation electricity facility in Brooklyn, Nova Scotia; and |
| a 50.0 per cent joint venture interest in Bear Swamp Power Company LLC (Bear Swamp), a 660 MW pumped storage hydroelectric facility in northwestern Massachusetts. |
| Emera US Finance LP (Emera Finance) and TECO Finance, Inc. (TECO Finance), financing subsidiaries of Emera; |
| Block Energy LLC (previously Emera Technologies LLC), a wholly owned technology company focused on finding ways to deliver renewable and resilient energy to customers; |
| Emera US Holdings Inc., a wholly owned holding company for certain of Emeras assets located in the United States; and |
| Other investments. |
BASIS OF PRESENTATION
These consolidated financial statements are prepared and presented in accordance with United States Generally Accepted Accounting Principles (USGAAP) and in the opinion of management, 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 (CAD), unless otherwise indicated.
PRINCIPLES OF CONSOLIDATION
These consolidated financial statements 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 VIEs in which Emera is not the primary beneficiary.
The Company performs ongoing analysis to assess whether it holds any VIEs or whether any reconsideration events have arisen with respect to existing VIEs. To identify potential VIEs, management reviews contractual and ownership arrangements such as leases, long-term purchase power agreements, tolling contracts, guarantees, jointly owned facilities and equity investments. VIEs of which the Company is deemed the primary beneficiary must be consolidated. The primary beneficiary of a VIE has both the power to direct the activities of the VIE that most significantly impacts its economic performance and the obligation to absorb losses or the right to receive benefits of the VIE that could potentially be significant to the VIE. In circumstances where Emera has an investment in a VIE but is not deemed the primary beneficiary, the VIE is accounted for using the equity method. For further details on VIEs, refer to note 32.
Intercompany balances and transactions have been eliminated on consolidation, except for the net profit on certain transactions between certain non-regulated and regulated entities in accordance with accounting standards for rate-regulated entities. The net profit on these transactions, which would be eliminated in the absence of the accounting standards for rate-regulated entities, is recorded in non-regulated operating revenues. An offset is recorded to PP&E, regulatory assets, regulated fuel for generation and purchased power, or 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 reported amounts of assets and liabilities at the date of the financial statements and reported amounts of revenues and expenses during the reporting periods. Significant areas requiring use of management estimates relate to rate-regulated assets and liabilities, accumulated reserve for cost of removal, pension and post-retirement benefits, unbilled revenue, useful lives for depreciable assets, goodwill and long-lived assets impairment assessments, income taxes, asset retirement obligations (ARO), and valuation of financial instruments. Management evaluates the Companys estimates on an ongoing basis based upon historical experience, current and expected conditions and assumptions believed to be reasonable at the time the assumption is made, with any adjustments recognized in income in the year they arise.
80 | EMERA 2023 ANNUAL REPORT |
Notes to the Consolidated Financial Statements
REGULATORY MATTERS
Regulatory accounting applies where rates are established by, or subject to approval by, an independent third-party regulator. Rates are designed to recover prudently incurred costs of providing regulated products or services and provide an opportunity for a reasonable rate of return on invested capital, as applicable. For further detail, refer to note 6.
FOREIGN CURRENCY TRANSLATION
Monetary assets and liabilities denominated in foreign currencies are converted to CAD 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 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 USD denominated debt held in CAD functional currency companies as hedges of net investments in USD denominated foreign operations. The change in the carrying amount of these investments, measured at exchange rates in effect at the balance sheet date is recorded in Other Comprehensive Income (OCI).
REVENUE RECOGNITION
Regulated Electric and Gas Revenue:
Electric and gas revenues, including energy charges, demand charges, basic facilities charges and clauses and riders, are recognized when obligations under the terms of a contract are satisfied, which is when electricity and gas are delivered to customers over time as the customer simultaneously receives and consumes the benefits. Electric and gas revenues are recognized on an accrual basis and include billed and unbilled revenues. Revenues related to the sale of electricity and gas are recognized at rates approved by the respective regulators and recorded based on metered usage, which occurs on a periodic, systematic basis, generally monthly or bi-monthly. At the end of each reporting period, electricity and gas delivered to customers, but not billed, is estimated and corresponding unbilled revenue is recognized. The Companys estimate of unbilled revenue at the end of the reporting period is calculated by estimating the megawatt hours (MWh) or therms delivered to customers at the established rates 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.
Non-regulated Revenue:
Marketing and trading margins are comprised of Emera Energys 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 the contract are satisfied and are presented on a net basis reflecting the nature of 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.
Other non-regulated revenues are recorded when obligations under the terms of the contract are satisfied.
Other:
Sales, value add, and other taxes, except for gross receipts taxes discussed below, collected by the Company concurrent with revenue-producing activities are excluded from revenue.
FRANCHISE FEES AND GROSS RECEIPTS
TEC 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 TEC and PGS are included as an expense on the Consolidated Statements of Income in Provincial, state and municipal taxes.
EMERA 2023 ANNUAL REPORT | 81 |
Notes to the Consolidated Financial Statements
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, NMGCs franchise fees and gross receipt taxes are presented net with no line item impact on the Consolidated Statements of Income.
PP&E
PP&E is recorded at original cost, including AFUDC or capitalized interest, net of contributions received in aid of construction.
The cost of additions, including betterments and replacements of units, are included in PP&E on the Consolidated Balance Sheets. When units of regulated PP&E 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 PP&E occurs, gains and losses are included in income as the dispositions occur.
The cost of PP&E represents the original cost of materials, contracted services, direct labour, AFUDC for regulated property or interest for non-regulated property, ARO, and overhead attributable to the capital project. Overhead includes corporate costs such as finance, information technology and labour costs, along with other costs related to support functions, employee benefits, insurance, procurement, and fleet operating and maintenance. Expenditures for project development are capitalized if they are expected to have a future economic benefit.
Normal maintenance projects and major maintenance projects that do not increase overall life of the related assets are expensed as incurred. 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 Emeras 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 regulatory approval.
Intangible assets, which are included in PP&E on the Consolidated Balance Sheets, consist primarily of computer software and land rights. Amortization is determined by the straight-line method, based on the estimated remaining service lives of the asset in each category. For some of Emeras rate-regulated subsidiaries, amortization is calculated using the amortizable life method which is applied to the net book value to date over the remaining life of those assets. The service lives of regulated intangible assets require regulatory approval.
GOODWILL
Goodwill is calculated as the excess of the purchase price of an acquired entity over the estimated FV of identifiable assets acquired and liabilities assumed at the acquisition date. Goodwill is carried at initial cost less any write-down for impairment and is adjusted for the impact of foreign exchange (FX). Goodwill is subject to assessment for impairment at the reporting unit level annually, or if an event or change in circumstances indicates that the FV of a reporting unit may be below its carrying value. When assessing goodwill for impairment, the Company has the option of first performing a qualitative assessment to determine whether a quantitative assessment is necessary. In performing a qualitative assessment management considers, among other factors, macroeconomic conditions, industry and market considerations and overall financial performance.
If the Company performs a qualitative assessment and determines it is more likely than not that its FV is less than its carrying amount, or if the Company chooses to bypass the qualitative assessment, a quantitative test is performed. The quantitative test compares the FV of the reporting unit to its carrying amount, including goodwill. If the carrying amount of the reporting unit exceeds its FV, an impairment loss is recorded. Management estimates the FV of the reporting unit by using the income approach, or a combination of the income and market approach. The income approach uses a discounted cash flow analysis which relies on managements best estimate of the reporting units projected cash flows. The analysis includes an estimate of terminal values based on these expected cash flows using a methodology which derives a valuation using an assumed perpetual annuity based
on the reporting units 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. For the market approach, management estimates FV based on comparable companies and transactions within the utility industry. Significant assumptions used in estimating the FV of a reporting unit using an income approach include discount and growth rates, rate case assumptions including future cost of capital, valuation of the reporting units net operating loss (NOL) and projected operating and capital cash flows. Adverse changes in these assumptions could result in a future material impairment of the goodwill assigned to Emeras reporting units.
82 | EMERA 2023 ANNUAL REPORT |
Notes to the Consolidated Financial Statements
As of December 31, 2023, $5,868 million of Emeras goodwill represents the excess of the acquisition purchase price for TECO Energy (TEC, PGS and NMGC reporting units) over the FV assigned to identifiable assets acquired and liabilities assumed. In Q4 2023, qualitative assessments were performed for NMGC and PGS given the significant excess of FV over carrying amounts calculated during the last quantitative tests in Q4 2022 and Q4 2019, respectively. Management concluded it was more likely than not that the FV of these reporting units exceeded their respective carrying amounts, including goodwill. As such, no quantitative testing was required. Given the length of time passed since the last quantitative impairment test for the TEC reporting unit, Emera elected to bypass a qualitative assessment and performed a quantitative impairment assessment in Q4 2023 using a combination of the income and market approach. This assessment estimated that the FV of the TEC reporting unit exceeded its carrying amount, including goodwill, and as a result, no impairment charges were recognized.
In Q4 2022, as a result of a quantitative assessment, the Company recorded a goodwill impairment charge of $73 million, reducing the GBPC goodwill balance to nil as at December 31, 2022. For further details, refer to note 22.
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 financial statements or income tax returns. Deferred income tax assets and liabilities are determined based on the difference between the carrying value of assets and liabilities on the Consolidated Balance Sheets, and their respective tax bases using enacted tax rates in effect for the year in which the differences are expected to reverse. The effect of a change in income tax rates on deferred income tax assets and liabilities is recognized in earnings in the period when the change is enacted, unless required to be offset to a regulatory asset or liability by law or by order of the regulator. Emera recognizes the effect of income tax positions only when it is more likely than not that they will be realized. Management reviews all readily available current and historical information, including forward-looking information, and the likelihood that deferred income tax assets will be recovered from future taxable income is assessed and assumptions are made about the expected timing of reversal of deferred income tax assets and liabilities. If management subsequently determines it is likely that some or all of a deferred income tax asset will not be realized, a valuation allowance is recorded to reflect the amount of deferred income tax asset 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 on regulated assets by TEC, PGS and NMGC are deferred and amortized as required by regulatory practices.
TEC, PGS, NMGC and BLPC collect income taxes from customers based on current and deferred income taxes. NSPI, ENL and Brunswick Pipeline collect income taxes from customers based on income tax that is currently payable, except for the deferred income taxes on certain regulatory balances specifically prescribed by regulators. For the balance of regulated deferred income taxes, NSPI, ENL and Brunswick Pipeline recognize regulatory assets or liabilities where the deferred income taxes are expected to be recovered from or returned to customers in future years. These regulated assets or liabilities are grossed up using the respective income tax rate to reflect the income tax associated with future revenues that are required to fund these deferred income tax liabilities, and the income tax benefits associated with reduced revenues resulting from the realization of deferred income tax assets. GBPC is not subject to income taxes.
Emera classifies interest and penalties associated with unrecognized tax benefits as interest and operating expense, respectively. For further detail, refer to note 10.
DERIVATIVES AND HEDGING ACTIVITIES
The Company manages its exposure to normal operating and market risks relating to commodity prices, FX, interest rates and share prices through contractual protections with counterparties where practicable, and by using financial instruments consisting mainly of FX 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 HFT. Collectively, these contracts and financial instruments are considered derivatives.
EMERA 2023 ANNUAL REPORT | 83 |
Notes to the Consolidated Financial Statements
The Company recognizes the FV of all its derivatives on its balance sheet, except for non-financial derivatives that meet the normal purchases and normal sales (NPNS) exception. Physical contracts that meet the NPNS exception are not recognized on the balance sheet; these contracts are recognized in income when they settle. A physical contract generally qualifies for the NPNS exception if the transaction is reasonable in relation to the Companys 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 if the criteria are no longer met.
Derivatives qualify for hedge accounting if they meet stringent documentation requirements and can be proven to effectively hedge identified risk both at the inception and over the term of the instrument. Specifically, for cash flow hedges, change in the FV of derivatives is deferred to AOCI and recognized in income in the same period the related hedged item is realized. Where documentation or effectiveness requirements are not met, the derivatives are recognized at FV with any changes in FV recognized in net income in the reporting period, unless deferred as a result of regulatory accounting.
Derivatives entered into by NSPI, NMGC and GBPC that are documented as economic hedges or for which the NPNS exception has not been taken, are subject to regulatory accounting treatment. The change in FV 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. TEC has no derivatives related to hedging as a result of a FPSC approved five-year moratorium on hedging of natural gas purchases that ended on December 31, 2022 and was extended through December 31, 2024 as a result of TECs 2021 rate case settlement agreement.
Derivatives that do not meet any of the above criteria are designated as HFT, with changes in FV normally recorded in net income of the period. The Company has not elected to designate any derivatives to be included in the HFT category where another accounting treatment would apply.
Emera classifies gains and losses on derivatives as a component of non-regulated operating revenues, fuel for generation and purchased power, other expenses, inventory, and OM&G, depending on the nature of the item being economically hedged. Transportation capacity arising as a result of marketing and trading derivative transactions is recognized as an asset in Receivables and other current assets and amortized over the period of the transportation contract term. Cash flows from derivative activities are presented in the same category as the item being hedged within operating or investing activities on the Consolidated Statements of Cash Flows. Non-hedged derivatives are included in operating cash flows on the Consolidated Statements of Cash Flows.
Derivatives, as reflected on the Consolidated Balance Sheets, are not offset by the FV 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.
LEASES
The Company determines whether a contract contains a lease at inception by evaluating whether the contract conveys the right to control the use of an identified asset for a period of time in exchange for consideration.
Emera has leases with independent power producers (IPP) and other utilities for annual requirements to purchase wind and hydro energy over varying contract lengths which are classified as finance leases. These finance leases are not recorded on the Companys Consolidated Balance Sheets as payments associated with the leases are variable in nature and there are no minimum fixed lease payments. Lease expense associated with these leases is recorded as Regulated fuel for generation and purchased power on the Consolidated Statements of Income.
Operating lease liabilities and right-of-use assets are recognized on the Consolidated Balance Sheets based on the present value of the future minimum lease payments over the lease term at commencement date. As most of Emeras leases do not provide an implicit rate, the incremental borrowing rate at commencement of the lease is used in determining the present value of future lease payments. Lease expense is recognized on a straight-line basis over the lease term and is recorded as Operating, maintenance and general on the Consolidated Statements of Income.
84 | EMERA 2023 ANNUAL REPORT |
Notes to the Consolidated Financial Statements
Where the Company is the lessor, a lease is a sales-type lease if certain criteria are met and the arrangement transfers control of the underlying asset to the lessee. For arrangements where the criteria are met due to the presence of a third-party residual value guarantee, the lease is a direct financing lease.
For direct finance leases, a net investment in the lease is recorded that consists of the sum of the minimum lease payments and residual value, net of estimated executory costs and unearned income. The difference between the gross investment and the cost of the leased item is recorded as unearned income at the inception of the lease. Unearned income is recognized in income over the life of the lease using a constant rate of interest equal to the internal rate of return on the lease.
For sales-type leases, the accounting is similar to the accounting for direct finance leases however, the difference between the FV and the carrying value of the leased item is recorded at lease commencement rather than deferred over the term of the lease.
Emera has certain contractual agreements that include lease and non-lease components, which management has elected to account for as a single lease component.
CASH, CASH EQUIVALENTS AND RESTRICTED CASH
Cash equivalents consist of highly liquid short-term investments with original maturities of three months or less at acquisition.
RECEIVABLES AND ALLOWANCE FOR CREDIT LOSSES
Utility customer receivables are recorded at the invoiced amount and do not bear interest. Standard payment terms for electricity and gas sales are approximately 30 days. A late payment fee may be assessed on account balances after the due date. The Company recognizes allowances for credit losses to reduce accounts receivable for amounts expected to be uncollectable. Management estimates credit losses related to accounts receivable by considering historical loss experience, customer deposits, current events, the characteristics of existing accounts and reasonable and supportable forecasts that affect the collectability of the reported amount. Provisions for credit losses on receivables are expensed to maintain the allowance at a level considered adequate to cover expected losses. Receivables are written off against the allowance when they are deemed uncollectible.
INVENTORY
Fuel and materials inventories are valued at the lower of weighted-average cost or net realizable value, unless evidence indicates the weighted-average cost will be recovered in future customer rates.
ASSET IMPAIRMENT
Long-Lived Assets:
Emera assesses whether there has been an impairment of long-lived assets and intangibles when a triggering event occurs, such as a significant market disruption or sale of a business.
The assessment involves comparing 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 FV. The Companys 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 Companys expectations regarding uses and holding periods of assets are based on internal long-term budgets and projections, which consider external factors and market forces, as of the end of each reporting period. The assumptions made are consistent with generally accepted industry approaches and assumptions used for valuation and pricing activities.
As at December 31, 2023, there are no indications of impairment of Emeras long-lived assets. No impairment charges related to long-lived assets were recognized in 2023 or 2022.
Equity Method Investments:
The carrying value of investments accounted for under the equity method are assessed for impairment by comparing the FV of these investments to their carrying values, if a FV 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 investments FV. No impairment of equity method investments was required in either 2023 or 2022.
EMERA 2023 ANNUAL REPORT | 85 |
Notes to the Consolidated Financial Statements
Financial Assets:
Equity investments, other than those accounted for under the equity method, are measured at FV, with changes in FV recognized in the Consolidated Statements of Income. Equity investments that do not have readily determinable FV are recorded at cost minus impairment, if any, plus or minus changes resulting from observable price changes in orderly transactions for the identical or similar investments. No impairment of financial assets was required in either 2023 or 2022.
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 FV of estimated cash flows necessary to discharge the future obligation, using the Companys credit adjusted risk-free rate. The amounts are reduced by actual expenditures incurred. Estimated future cash flows are based on completed depreciation studies, remediation reports, prior experience, estimated useful lives, and governmental regulatory requirements. The present value of the liability is recorded and the carrying amount of the related long-lived asset is correspondingly increased. The amount capitalized at inception is depreciated in the same manner as the related long-lived asset. Over time, the liability is accreted to its estimated future value. AROs are included in Other long-term liabilities and accretion expense is included as part of Depreciation and amortization. Any regulated accretion expense not yet approved by the regulator is recorded in Property, plant and equipment and included in the next depreciation study.
Some of the Companys transmission and distribution assets may have conditional AROs that are not recognized in the consolidated financial statements, as the FV of these obligations could not be reasonably estimated, given 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 FV in the period in which an amount can be determined.
COST OF REMOVAL (COR)
TEC, PGS, NMGC and NSPI recognize non-ARO COR as regulatory liabilities. The non-ARO COR represent funds received from customers through depreciation rates to cover estimated future non-legally required COR of PP&E upon retirement. The companies accrue for COR over the life of the related assets based on depreciation studies approved by their respective regulators. The costs are estimated based on historical experience and future expectations, including expected timing and estimated future cash outlays.
STOCK-BASED COMPENSATION
The Company has several stock-based compensation plans: a common share option plan for senior management; an employee common share purchase plan; a deferred share unit (DSU) plan; a performance share unit (PSU) plan; and a restricted share unit (RSU) plan. The Company accounts for its plans in accordance with the FV-based method of accounting for stock-based compensation. Stock-based compensation cost is measured at the grant date, based on the calculated FV of the award, and is recognized as an expense over the employees or directors requisite service period using the graded vesting method. Stock- based compensation plans recognized as liabilities are initially measured at FV and re-measured at FV at each reporting date, with the change in liability recognized in income
EMPLOYEE BENEFITS
The costs of the Companys 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 unamortized gains and losses and past service costs in AOCI or Regulatory assets on the Consolidated Balance Sheets. The components of net periodic benefit cost other than the service cost component are included in Other income, net on the Consolidated Statements of Income. For further detail, refer to note 21.
86 | EMERA 2023 ANNUAL REPORT |
Notes to the Consolidated Financial Statements
2. Future Accounting Pronouncements
The Company considers the applicability and impact of all ASUs issued by the Financial Accounting Standards Board (FASB). The following updates have been issued by the FASB, but as allowed, have not yet been adopted by Emera. Any ASUs not included below were assessed and determined to be either not applicable to the Company or to have an insignificant impact on the consolidated financial statements.
IMPROVEMENTS TO INCOME TAX DISCLOSURES
In December 2023, the FASB issued ASU 2023-09, Income Taxes (Topic 740): Improvements to Income Tax Disclosures. The standard enhances the transparency, decision usefulness and effectiveness of income tax disclosures by requiring consistent categories and greater disaggregation of information in the reconciliation of income taxes computed using the enacted statutory income tax rate to the actual income tax provision and effective income tax rate, as well as the disaggregation of income taxes paid (refunded) by jurisdiction. The standard also requires disclosure of income (loss) before provision for income taxes and income tax expense (recovery) in accordance with U.S. Securities and Exchange Commission Regulation S-X 210.4-08(h), Rules of General Application General Notes to Financial Statements: Income Tax Expense, and the removal of disclosures no longer considered cost beneficial or relevant. The guidance will be effective for annual reporting periods beginning after December 15, 2024, and interim periods within annual reporting periods beginning after December 15, 2025. Early adoption is permitted. The standard will be applied on a prospective basis, with retrospective application permitted. The Company is currently evaluating the impact of adoption of the standard on its consolidated financial statements.
IMPROVEMENTS TO REPORTABLE SEGMENT DISCLOSURES
In November 2023, the FASB issued ASU 2023-07, Segment Reporting (Topic 280), Improvements to Reportable Segment Disclosures. The change in the standard improves reportable segment disclosure requirements, primarily through enhanced disclosures about significant segment expenses. The changes improve financial reporting by requiring disclosure of incremental segment information on an annual and interim basis for all public entities to enable investors to develop more decision-useful financial analyses. The guidance will be effective for annual reporting periods beginning after December 15, 2023, and for interim periods beginning after December 15, 2024. Early adoption is permitted. The standard will be applied retrospectively. The Company is currently evaluating the impact of adoption of the standard on its consolidated financial statements.
3. Dispositions
On March 31, 2022, Emera completed the sale of its 51.9 per cent interest in Domlec for proceeds which approximated its carrying value. Domlec was included in the Companys Other Electric reportable segment up to its date of sale. The sale did not have a material impact on earnings.
EMERA 2023 ANNUAL REPORT | 87 |
Notes to the Consolidated Financial Statements
4. Segment Information
Emera manages its reportable segments separately due in part to their different operating, regulatory and geographical environments. Segments are reported based on each subsidiarys contribution of revenues, net income attributable to common shareholders and total assets, as reported to the Companys chief operating decision maker.
millions of dollars |
Florida Electric Utility |
Canadian Electric Utilities |
Gas Utilities and Infrastructure |
Other Electric Utilities |
Other | Inter- Segment Eliminations |
Total | |||||||||||||||||||||
For the year ended December 31, 2023 |
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Operating revenues from external customers (1) |
$ | 3,548 | $ | 1,671 | $ | 1,510 | $ | 526 | $ | 308 | $ | | $ | 7,563 | ||||||||||||||
Inter-segment revenues (1) |
8 | | 14 | | 31 | (53 | ) | | ||||||||||||||||||||
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Total operating revenues |
3,556 | 1,671 | 1,524 | 526 | 339 | (53 | ) | 7,563 | ||||||||||||||||||||
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Regulated fuel for generation and purchased power |
920 | 699 | | 275 | | (13 | ) | 1,881 | ||||||||||||||||||||
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Regulated cost of natural gas |
| | 527 | | | | 527 | |||||||||||||||||||||
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OM&G |
830 | 384 | 405 | 130 | 151 | (21 | ) | 1,879 | ||||||||||||||||||||
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Provincial, state and municipal taxes |
289 | 45 | 91 | 3 | 5 | | 433 | |||||||||||||||||||||
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Depreciation and amortization |
571 | 276 | 126 | 68 | 8 | | 1,049 | |||||||||||||||||||||
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Income from equity investments |
| 109 | 21 | 4 | 12 | | 146 | |||||||||||||||||||||
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Other income, net |
69 | 32 | 11 | 7 | 20 | 19 | 158 | |||||||||||||||||||||
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Interest expense, net (2) |
271 | 170 | 129 | 23 | 332 | | 925 | |||||||||||||||||||||
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Income tax expense (recovery) |
117 | (9 | ) | 64 | | (44 | ) | | 128 | |||||||||||||||||||
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Non-controlling interest in subsidiaries |
| | | 1 | | | 1 | |||||||||||||||||||||
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Preferred stock dividends |
| | | | 66 | | 66 | |||||||||||||||||||||
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Net income (loss) attributable to common shareholders |
$ | 627 | $ | 247 | $ | 214 | $ | 37 | $ | (147 | ) | $ | | $ | 978 | |||||||||||||
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Capital expenditures |
$ | 1,736 | $ | 450 | $ | 664 | $ | 63 | $ | 8 | $ | | $ | 2,921 | ||||||||||||||
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As at December 31, 2023 |
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Total assets |
$ | 21,119 | $ | 8,634 | $ | 7,735 | $ | 1,311 | $ | 1,938 | $ | (1,257 | ) | $ | 39,480 | |||||||||||||
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Investments subject to significant influence |
$ | | $ | 1,236 | $ | 118 | $ | 48 | $ | | $ | | $ | 1,402 | ||||||||||||||
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Goodwill |
$ | 4,628 | $ | | $ | 1,240 | $ | | $ | 3 | $ | | $ | 5,871 | ||||||||||||||
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(1) | All significant inter-company balances and transactions have been eliminated on consolidation except for certain transactions between non-regulated and regulated entities. Management believes elimination of these transactions would understate PP&E, OM&G, or regulated fuel for generation and purchased power. Inter-company transactions that have not been eliminated are measured at the amount of consideration established and agreed to by the related parties. Eliminated transactions are included in determining reportable segments. |
(2) | Segment net income is reported on a basis that includes internally allocated financing costs of $95 million for the year ended December 31, 2023, between the Florida Electric Utility, Gas Utilities and Infrastructure and Other segments. |
88 | EMERA 2023 ANNUAL REPORT |
Notes to the Consolidated Financial Statements
millions of dollars |
Florida Electric Utility |
Canadian Electric Utilities |
Gas Utilities and Infrastructure |
Other Electric Utilities |
Other | Inter- Segment Eliminations |
Total | |||||||||||||||||||||
For the year ended December 31, 2022 |
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Operating revenues from external customers (1) |
$ | 3,280 | $ | 1,675 | $ | 1,697 | $ | 518 | $ | 418 | $ | | $ | 7,588 | ||||||||||||||
Inter-segment revenues (1) |
7 | | 7 | | 22 | (36 | ) | | ||||||||||||||||||||
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Total operating revenues |
3,287 | 1,675 | 1,704 | 518 | 440 | (36 | ) | 7,588 | ||||||||||||||||||||
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Regulated fuel for generation and purchased power |
1,086 | 803 | | 290 | | (8 | ) | 2,171 | ||||||||||||||||||||
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Regulated cost of natural gas |
| | 800 | | | | 800 | |||||||||||||||||||||
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OM&G |
625 | 338 | 365 | 123 | 156 | (11 | ) | 1,596 | ||||||||||||||||||||
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Provincial, state and municipal taxes |
235 | 43 | 83 | 3 | 3 | | 367 | |||||||||||||||||||||
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Depreciation and amortization |
507 | 259 | 118 | 61 | 7 | | 952 | |||||||||||||||||||||
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Income from equity investments |
| 87 | 21 | 4 | 17 | | 129 | |||||||||||||||||||||
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Other income (expenses), net |
68 | 24 | 13 | | 23 | 17 | 145 | |||||||||||||||||||||
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Interest expense, net (2) |
185 | 136 | 81 | 19 | 288 | | 709 | |||||||||||||||||||||
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GBPC impairment charge |
| | | 73 | | | 73 | |||||||||||||||||||||
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Income tax expense (recovery) |
121 | (8 | ) | 70 | | 2 | | 185 | ||||||||||||||||||||
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Non-controlling interest in subsidiaries |
| | | 1 | | | 1 | |||||||||||||||||||||
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Preferred stock dividends |
| | | | 63 | | 63 | |||||||||||||||||||||
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Net income (loss) attributable to common shareholders |
$ | 596 | $ | 215 | $ | 221 | $ | (48 | ) | $ | (39 | ) | $ | | $ | 945 | ||||||||||||
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Capital expenditures |
$ | 1,425 | $ | 507 | $ | 574 | $ | 63 | $ | 6 | $ | | $ | 2,575 | ||||||||||||||
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As at December 31, 2022 |
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Total assets |
$ | 21,053 | $ | 8,223 | $ | 7,737 | $ | 1,337 | $ | 2,835 | $ | (1,443 | ) | $ | 39,742 | |||||||||||||
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Investments subject to significant influence |
$ | | $ | 1,241 | $ | 128 | $ | 49 | $ | | $ | | $ | 1,418 | ||||||||||||||
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Goodwill |
$ | 4,739 | $ | | $ | 1,270 | $ | | $ | 3 | $ | | $ | 6,012 | ||||||||||||||
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(1) | All significant inter-company balances and transactions have been eliminated on consolidation except for certain transactions between non-regulated and regulated entities. Management believes elimination of these transactions would understate PP&E, OM&G, or regulated fuel for generation and purchased power. Inter-company transactions that have not been eliminated are measured at the amount of consideration established and agreed to by the related parties. Eliminated transactions are included in determining reportable segments. |
(2) | Segment net income is reported on a basis that includes internally allocated financing costs of $13 million for the year ended December 31, 2022, between the Gas Utilities and Infrastructure and Other segments. |
GEOGRAPHICAL INFORMATION
Revenues (based on country of origin of the product or service sold)
For the | Year ended December 31 | |||||||
millions of dollars |
2023 | 2022 | ||||||
United States |
$ | 5,310 | $ | 5,346 | ||||
Canada |
1,727 | 1,725 | ||||||
Barbados |
389 | 384 | ||||||
The Bahamas |
137 | 122 | ||||||
Dominica |
| 11 | ||||||
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|||||
$ | 7,563 | $ | 7,588 | |||||
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Property Plant and Equipment:
As at millions of dollars |
December 31 2023 |
December 31 2022 |
||||||
United States |
$ | 18,588 | $ | 17,382 | ||||
Canada |
4,878 | 4,689 | ||||||
Barbados |
576 | 583 | ||||||
The Bahamas |
334 | 342 | ||||||
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$ | 24,376 | $ | 22,996 | |||||
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EMERA 2023 ANNUAL REPORT | 89 |
Notes to the Consolidated Financial Statements
5. Revenue
The following disaggregates the Companys revenue by major source:
Electric | Gas | Other | ||||||||||||||||||||||||||
millions of dollars |
Florida Electric Utility |
Canadian Electric Utilities |
Other Electric Utilities |
Gas Utilities and Infrastructure |
Other | Inter- Segment Eliminations |
Total | |||||||||||||||||||||
For the year ended December 31, 2023 |
||||||||||||||||||||||||||||
Regulated Revenue |
||||||||||||||||||||||||||||
Residential |
$ | 2,307 | $ | 910 | $ | 183 | $ | 724 | $ | | $ | | $ | 4,124 | ||||||||||||||
Commercial |
1,083 | 463 | 285 | 425 | | | 2,256 | |||||||||||||||||||||
Industrial |
274 | 219 | 33 | 93 | | (13 | ) | 606 | ||||||||||||||||||||
Other electric |
395 | 41 | 7 | | | | 443 | |||||||||||||||||||||
Regulatory deferrals |
(522 | ) | | 12 | | | | (510 | ) | |||||||||||||||||||
Other (1) |
19 | 38 | 6 | 199 | | (8 | ) | 254 | ||||||||||||||||||||
Finance income (2) (3) |
| | | 62 | | 62 | ||||||||||||||||||||||
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Regulated revenue |
$ | 3,556 | $ | 1,671 | $ | 526 | $ | 1,503 | $ | | $ | (21 | ) | $ | 7,235 | |||||||||||||
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Non-Regulated Revenue |
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Marketing and trading margin (4) |
| | | | 96 | | 96 | |||||||||||||||||||||
Other non-regulated operating revenue |
| | | 21 | 27 | (23 | ) | 25 | ||||||||||||||||||||
Mark-to-market (3) |
| | | | 216 | (9 | ) | 207 | ||||||||||||||||||||
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Non-regulated revenue |
$ | | $ | | $ | | $ | 21 | $ | 339 | $ | (32 | ) | $ | 328 | |||||||||||||
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Total operating revenues |
$ | 3,556 | $ | 1,671 | $ | 526 | $ | 1,524 | $ | 339 | $ | (53 | ) | $ | 7,563 | |||||||||||||
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For the year ended December 31, 2022 |
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Regulated Revenue |
||||||||||||||||||||||||||||
Residential |
$ | 1,799 | $ | 834 | $ | 184 | $ | 800 | $ | | $ | | $ | 3,617 | ||||||||||||||
Commercial |
869 | 427 | 282 | 461 | | | 2,039 | |||||||||||||||||||||
Industrial |
230 | 353 | 32 | 83 | | (7 | ) | 691 | ||||||||||||||||||||
Other electric |
398 | 28 | 6 | | | | 432 | |||||||||||||||||||||
Regulatory deferrals |
(27 | ) | | 6 | | | | (21 | ) | |||||||||||||||||||
Other (1) |
18 | 33 | 8 | 283 | | (7 | ) | 335 | ||||||||||||||||||||
Finance income (2) (3) |
| | | 61 | | | 61 | |||||||||||||||||||||
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Regulated revenue |
$ | 3,287 | $ | 1,675 | $ | 518 | $ | 1,688 | $ | | $ | (14 | ) | $ | 7,154 | |||||||||||||
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Non-Regulated |
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Marketing and trading margin (4) |
| | | | 143 | | 143 | |||||||||||||||||||||
Other non-regulated operating revenue |
| | | 16 | 16 | (10 | ) | 22 | ||||||||||||||||||||
Mark-to-market (3) |
| | | | 281 | (12 | ) | 269 | ||||||||||||||||||||
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Non-regulated revenue |
$ | | $ | | $ | | $ | 16 | $ | 440 | $ | (22 | ) | $ | 434 | |||||||||||||
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Total operating revenues |
$ | 3,287 | $ | 1,675 | $ | 518 | $ | 1,704 | $ | 440 | $ | (36 | ) | $ | 7,588 | |||||||||||||
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(1) | Other includes rental revenues, which do not represent revenue from contracts with customers. |
(2) | Revenue related to Brunswick Pipelines service agreement with Repsol Energy Canada. |
(3) | Revenue which does not represent revenues from contracts with customers. |
(4) | Includes gains (losses) on settlement of energy related derivatives, which do not represent revenue from contracts with customers. |
Remaining Performance Obligations
Remaining performance obligations primarily represent gas transportation contracts, lighting contracts, and long-term steam supply arrangements with fixed contract terms. As of December 31, 2023, the aggregate amount of the transaction price allocated to remaining performance obligations was $488 million (2022 - $450 million). This amount includes $134 million of future performance obligations related to a gas transportation contract between SeaCoast and PGS through 2040. This amount excludes contracts with an original expected length of one year or less and variable amounts for which Emera recognizes revenue at the amount to which it has the right to invoice for services performed. Emera expects to recognize revenue for the remaining performance obligations through 2043.
90 | EMERA 2023 ANNUAL REPORT |
Notes to the Consolidated Financial Statements
6. Regulatory Assets and Liabilities
Regulatory assets represent prudently incurred costs that have been deferred because it is probable they will be recovered through future rates or tolls collected from customers. Management believes existing regulatory assets are probable for recovery either because the Company received specific approval from the applicable regulator, or due to regulatory precedent established for similar circumstances. If management no longer considers it probable that an asset will be recovered, 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.
As at millions of dollars |
December 31 2023 |
December 31 2022 |
||||||
Regulatory assets |
||||||||
Deferred income tax regulatory assets |
$ | 1,233 | $ | 1,166 | ||||
TEC capital cost recovery for early retired assets |
671 | 674 | ||||||
NSPI FAM |
395 | 307 | ||||||
Pension and post-retirement medical plan |
364 | 369 | ||||||
Cost recovery clauses |
151 | 707 | ||||||
Deferrals related to derivative instruments |
88 | 30 | ||||||
Storm cost recovery clauses |
52 | 138 | ||||||
Environmental remediations |
26 | 27 | ||||||
Stranded cost recovery |
25 | 27 | ||||||
NMGC winter event gas cost recovery |
| 69 | ||||||
Other |
100 | 106 | ||||||
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|||||
$ | 3,105 | $ | 3,620 | |||||
|
|
|
|
|||||
Current |
$ | 339 | $ | 602 | ||||
Long-term |
2,766 | 3,018 | ||||||
|
|
|
|
|||||
Total regulatory assets |
$ | 3,105 | $ | 3,620 | ||||
|
|
|
|
|||||
Regulatory liabilities |
||||||||
Accumulated reserve - COR |
849 | 895 | ||||||
Deferred income tax regulatory liabilities |
830 | 877 | ||||||
Cost recovery clauses |
32 | 70 | ||||||
BLPC Self-insurance fund (SIF) (note 32) |
29 | 30 | ||||||
Deferrals related to derivative instruments |
17 | 230 | ||||||
NMGC gas hedge settlements (note 18) |
| 162 | ||||||
Other |
15 | 9 | ||||||
|
|
|
|
|||||
$ | 1,772 | $ | 2,273 | |||||
|
|
|
|
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Current |
$ | 168 | $ | 495 | ||||
Long-term |
1,604 | 1,778 | ||||||
|
|
|
|
|||||
Total regulatory liabilities |
$ | 1,772 | $ | 2,273 | ||||
|
|
|
|
Deferred Income Tax Regulatory Assets and Liabilities
To the extent deferred income taxes are expected to be recovered from or returned to customers in future years, a regulatory asset or liability is recognized as appropriate.
EMERA 2023 ANNUAL REPORT | 91 |
Notes to the Consolidated Financial Statements
TEC Capital Cost Recovery for Early Retired Assets
This regulatory asset is related to the remaining net book value of Big Bend Power Station Units 1 through 3 and smart meter assets that were retired. The balance earns a rate of return as permitted by the FPSC and is recovered as a separate line item on customer bills for a period of 15 years. This recovery mechanism is authorized by and survives the term of the settlement agreement approved by the FPSC in 2021. For further information, refer to Big Bend Modernization Project in the TEC section below.
NSPI FAM
NSPI has a FAM, approved by the UARB, allowing NSPI to recover fluctuating fuel and certain fuel-related costs from customers through regularly scheduled 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 subsequent periods.
Pension and Post-Retirement Medical Plan
This asset is primarily related to the deferred costs of pension and post-retirement benefits at TEC, PGS and NMGC. It is included in rate base and earns a rate of return as permitted by the FPSC and NMPRC, as applicable. It is amortized over the remaining service life of plan participants.
Cost Recovery Clauses
These assets and liabilities are related to TEC, PGS and NMGC clauses and riders. They are recovered or refunded through cost- recovery mechanisms approved by the FPSC or New Mexico Public Regulation Commission (NMPRC), as applicable, on a dollar- for-dollar basis in a subsequent period.
Deferrals Related to Derivative Instruments
This asset is primarily related to NSPI deferring changes in FV 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 UARB. The realized gain or loss is recognized when the hedged item settles in regulated fuel for generation and purchased power, other income, inventory, or OM&G, depending on the nature of the item being economically hedged.
Storm Cost Recovery Clauses
TEC and PGS Storm Reserve:
The storm reserve is for hurricanes and other named storms that cause significant damage to TEC and PGS systems. As allowed by the FPSC, if charges to the storm reserve exceed the storm liability, the excess is to be carried as a regulatory asset. TEC and PGS can petition the FPSC to seek recovery of restoration costs over a 12-month period or longer, as determined by the FPSC, as well as replenish the reserve. In 2022, TEC and PGS were impacted by Hurricane Ian. For further information, refer to TEC Storm Reserve in the Florida Electric Utility section below.
NSPI Storm Rider:
NSPI has a UARB approved storm rider for each of 2023, 2024 and 2025, which gives NSPI the option to apply to the UARB for recovery of costs if major storm restoration expenses exceed approximately $10 million in a given year.
GBPC Storm Restoration:
This asset represents storm restoration costs incurred by GBPC. GBPC maintains insurance for its generation facilities and, as with most utilities, its transmission and distribution networks are not covered by commercial insurance.
In January 2020, the Grand Bahama Port Authority (GBPA) approved recovery of $15 million USD of 2019 costs related to Hurricane Dorian, over a five-year period from 2021 through 2025.
Restoration costs associated with Hurricane Matthew in 2016 are being recovered through an approved fuel charge. For further information, refer to Storm Restoration Costs Hurricane Matthew in the GBPC section below.
92 | EMERA 2023 ANNUAL REPORT |
Notes to the Consolidated Financial Statements
Environmental Remediations
This asset is primarily related to PGS costs associated with environmental remediation at Manufactured Gas Plant sites. The balance is included in rate base, partially offsetting the related liability, and earns a rate of return as permitted by the FPSC. The timing of recovery is based on a settlement agreement approved by the FPSC.
Stranded Cost Recovery
Due to decommissioning of a GBPC steam turbine in 2012, the GBPA approved recovery of a $21 million USD stranded cost through electricity rates; it is included in rate base and expected to be included in rates in future years.
NMGC Winter Event Gas Cost Recovery
In February 2021, the State of New Mexico experienced an extreme cold weather event that resulted in an incremental $108 million USD for gas costs above what it would normally have paid during this period. NMGC normally recovers gas supply and related costs through a purchased gas adjustment clause (PGAC). On June 15, 2021, the NMPRC approved recovery of $108 million USD and related borrowing costs in customer rates over a period of 30 months from July 1, 2021, to December 31, 2023.
Accumulated Reserve COR
This regulatory liability represents the non-ARO COR reserve in TEC, PGS, NMGC and NSPI. AROs represent the FV of estimated cash flows associated with the Companys legal obligation to retire its PP&E. Non-ARO COR represent estimated funds received from customers through depreciation rates to cover future COR of PP&E value upon retirement that are not legally required. This 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.
NMGC Gas Hedge Settlements
This regulatory liability represents regulatory deferral of gas options exercised above strike price but settled subsequent to the period end. The value from cash settlement of these options flows to customers via the PGAC.
Other Regulatory Assets and Liabilities
Comprised of regulatory assets and liabilities that are not individually significant.
REGULATORY ENVIRONMENTS AND UPDATES
Florida Electric Utility
TEC is regulated by the FPSC and is also subject to regulation by the Federal Energy Regulatory Commission. The FPSC sets rates at a level that allows utilities such as TEC to collect total revenues or revenue requirements equal to their cost of providing service, plus an appropriate return on invested capital. Base rates are determined in FPSC rate setting hearings which can occur at the initiative of TEC, the FPSC or other interested parties.
TECs approved regulated return on equity (ROE) range for 2023 and 2022 was 9.25 per cent to 11.25 per cent based on an allowed equity capital structure of 54 per cent. An ROE of 10.20 per cent (2022 10.20 per cent) is used for the calculation of the return on investments for clauses.
Base Rates:
On February 1, 2024, TEC notified the FPSC of its intent to seek a base rate increase effective January 2025, reflecting a revenue requirement increase of approximately $290 to $320 million USD and additional adjustments of approximately $100 million USD and $70 million USD for 2026 and 2027, respectively. TECs proposed rates include recovery of solar generation projects, energy storage capacity, a more resilient and modernized energy control center, and numerous other resiliency and reliability projects. The filing range amounts are estimates until TEC files its detailed case in April 2024. The FPSC is scheduled to hear the case in Q3 2024.
On August 16, 2023, TEC filed a petition to implement the 2024 Generation Base Rate Adjustment provisions pursuant to the 2021 rate case settlement agreement. Inclusive of TECs ROE adjustment, the increase of $22 million USD was approved by the FPSC on November 17, 2023.
EMERA 2023 ANNUAL REPORT | 93 |
Notes to the Consolidated Financial Statements
Fuel Recovery and Other Cost Recovery Clauses:
TEC has a fuel recovery clause approved by the FPSC, allowing the opportunity to recover fluctuating fuel expenses from customers through annual fuel rate adjustments. The FPSC annually approves cost-recovery rates for purchased power, capacity, environmental and conservation costs, including a return on capital invested. Differences between 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 subsequent periods.
On January 23, 2023, TEC requested an adjustment to its fuel charges to recover the 2022 fuel under-recovery of $518 million USD over a period of 21 months. The request also included an adjustment to 2023 projected fuel costs to reflect the reduction in natural gas prices since September 2022 for a projected reduction of $170 million USD for the balance of 2023. The changes were approved by the FPSC on March 7, 2023, and were effective beginning on April 1, 2023.
The mid-course fuel adjustment requested by TEC on January 19, 2022, was approved on March 1, 2022. The rate increase, effective with the first billing cycle in April 2022, covered higher fuel and capacity costs of $169 million USD, and was spread over customer bills from April 1, 2022 through December 2022.
Big Bend Modernization Project:
TEC invested $876 million USD, including $91 million USD of AFUDC, between 2018 and 2022 to modernize the Big Bend Power Station. The modernization project repowered Big Bend Unit 1 with natural gas combined-cycle technology and eliminated coal as this units fuel. As part of the modernization project, TEC in 2020 retired the Unit 1 components that would not be used in the modernized plant and did the same for Big Bend Unit 2 in 2021. TEC retired Big Bend Unit 3 in 2023 as it was in the best interests of the customers from an economic, environmental risk and operational perspective. On December 31, 2021, the remaining costs of the retired Big Bend coal generation assets, Units 1 through 3, of $636 million USD and $267 million USD in accumulated depreciation were reclassified to a regulatory asset on the balance sheet.
TECs 2021 settlement agreement provides for cost recovery of the Big Bend Modernization project in two phases. The first phase was a revenue increase to cover the costs of the assets in service during 2022, among other items. The remainder of the project costs were recovered as part of the 2023 subsequent year adjustment. The settlement agreement also includes a new charge to recover the remaining costs of the retired Big Bend coal generation assets, Units 1 through 3, which are spread over 15 years, effective January 1, 2022. This recovery mechanism was authorized by and survives the term of the settlement agreement approved by the FPSC in 2021.
Storm Reserve:
In September 2022, TEC was impacted by Hurricane Ian, with $119 million USD of restoration costs charged against TECs FPSC approved storm reserve. Total restoration costs charged to the storm reserve exceeded the reserve balance and have been deferred as a regulatory asset for future recovery.
On January 23, 2023, TEC petitioned the FPSC for recovery of the storm reserve regulatory asset and the replenishment of the balance in the storm reserve to the approved storm reserve level of $56 million USD, for a total of $131 million USD. The storm cost recovery surcharge was approved by the FPSC on March 7, 2023, and TEC began applying the surcharge in April 2023. Subsequently, on November 9, 2023, the FPSC approved TECs petition, filed on August 16, 2023, to update the total storm cost collection to $134 million USD. It also changed the collection of the expected remaining balance of $29 million USD as of December 31, 2023, from over the first three months of 2024 to over the 12 months of 2024. The storm recovery is subject to review of the underlying costs for prudency and accuracy by the FPSC.
In Q3 2023, TEC was impacted by Hurricane Idalia. The related storm restoration costs were approximately $35 million USD, which were charged to the storm reserve regulatory asset, resulting in minimal impact to earnings.
94 | EMERA 2023 ANNUAL REPORT |
Notes to the Consolidated Financial Statements
Storm Protection Cost Recovery Clause and Settlement Agreement:
The Storm Protection Plan (SPP) Cost Recovery Clause provides a process for Florida investor-owned utilities, including TEC, to recover transmission and distribution storm hardening costs for incremental activities not already included in base rates. Differences between prudently incurred clause-recoverable costs and amounts recovered from customers through electricity rates in a year are deferred and recovered from or returned to customers in a subsequent year. A settlement agreement was approved on August 10, 2020, and TECs cost recovery began in January 2021. The current approved plan addressed the years 2023, 2024 and 2025 and was approved by the FPSC on October 4, 2022.
Canadian Electric Utilities
NSPI
NSPI is a public utility as defined in the Public Utilities Act of Nova Scotia (Public Utilities Act) and is subject to regulation under the Public Utilities Act by the UARB. The Public Utilities Act gives the UARB supervisory powers over NSPIs operations and expenditures. Electricity rates for NSPIs customers are also 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 NSPIs or the UARBs request.
NSPI is regulated under a cost-of-service model, with rates set to recover prudently incurred costs of providing electricity service to customers and provide a reasonable return to investors. NSPIs approved regulated ROE range for 2023 and 2022 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 of approved rate base.
General Rate Application (GRA):
On February 2, 2023, the UARB approved the GRA settlement agreement between NSPI, key customer representatives and participating interest groups. This resulted in average customer rate increases of 6.9 per cent effective on February 2, 2023, and further average increases of 6.5 per cent on January 1, 2024, with any under or over-recovery of fuel costs addressed through the UARBs established FAM process. It also established a storm rider and a demand-side management rider. On March 27, 2023, the UARB issued a final order approving the electricity rates effective on February 2, 2023.
Fuel Recovery:
For the period of 2020 through 2022, NSPI operated under a three-year fuel stability plan with no fuel rate adjustments related to the under-recovery of fuel and fuel-related costs in the period.
On January 29, 2024, NSPI applied to the UARB for approval of a structure that would begin to recover the outstanding FAM balance. As part of the application, NSPI requested approval for the sale of $117 million of the FAM regulatory asset to Invest Nova Scotia, a provincial Crown corporation, with the proceeds paid to NSPI upon approval. NSPI has requested approval to collect from customers the amortization and financing costs of $117 million on behalf of Invest Nova Scotia over a 10-year period, and remit those amounts to Invest Nova Scotia as collected, reducing short-term customer rate increases relative to the currently established FAM process. If approved, this portion of the FAM regulatory asset would be removed from the Consolidated Balance Sheets and NSPI would collect the balance on behalf of Invest Nova Scotia in NSPI rates beginning in 2024.
Storm Rider:
The storm rider was effective as of the GRA decision date. The application for deferral and recovery of the storm rider is made in the year following the year of the incurred cost, with recovery beginning in the year after the application. Total major storm restoration expense for 2023 was $31 million, of which $21 million was deferred to the storm rider.
Hurricane Fiona:
On October 31, 2023, NSPI submitted an application to the UARB to defer $24 million in incremental operating costs incurred during Hurricane Fiona storm restoration efforts in September 2022. NSPI is seeking amortization of the costs over a period to be approved by the UARB during a future rate setting process. At December 31, 2023, the $24 million is deferred to Other long-term assets, pending UARB approval.
EMERA 2023 ANNUAL REPORT | 95 |
Notes to the Consolidated Financial Statements
Maritime Link:
The Maritime Link is a $1.8 billion (including AFUDC) transmission project including two 170-kilometre sub-sea cables, connecting the island of Newfoundland and Nova Scotia. The Maritime Link entered service on January 15, 2018 and NSPI started interim assessment payments to NSPML at that time.
Any difference between the amounts recovered from customers through rates and those approved by the UARB through the NSPML interim assessment application will be addressed through the FAM.
Nova Scotia Cap-and-Trade (Cap-and-Trade) Program:
As of December 31, 2022, the FAM included a cumulative $166 million in fuel costs related to the accrued purchase of emissions credits and $6 million related to credits purchased from provincial auctions. On March 16, 2023, the Province of Nova Scotia provided NSPI with emissions allowances sufficient to achieve compliance for the 2019 through 2022 period. As such, compliance costs accrued of $166 million were reversed in Q1 2023. The credits NSPI purchased from provincial auctions in the amount of $6 million were not refunded and no further costs were incurred to achieve compliance with the Cap-and-Trade Program.
Extra Large Industrial Active Demand Tariff:
On July 5, 2023, NSPI received approval from the UARB to change the methodology in which fuel cost recovery from an industrial customer is calculated. Due to significant volatility in commodity prices in 2022, the previous methodology did not result in a reasonable determination of the fuel cost to serve this customer. The change in methodology, effective January 1, 2022, results in a shifting of fuel costs from this industrial customer to the FAM. This adjustment was recorded in Q2 2023 resulting in a $51 million increase to the FAM regulatory asset and an offsetting decrease to unbilled revenue within Receivables and other current assets. This adjustment had minimal impact on earnings.
NSPML
Equity earnings from the Maritime Link are dependent on the approved ROE and operational performance of NSPML. NSPMLs approved regulated ROE range is 8.75 per cent to 9.25 per cent, based on an actual five-quarter average regulated common equity component of up to 30 per cent.
Nalcors Nova Scotia Block (NS Block) delivery obligations commenced on August 15, 2021 and delivery will continue over the next 35 years pursuant to the agreements.
In February 2022, the UARB issued its decision and Board Order approving NSPMLs requested rate base of approximately $1.8 billion less $9 million of costs ($7 million after-tax) that would not have otherwise been recoverable if incurred by NSPI.
On October 4, 2023 and January 31, 2024, the UARB issued decisions providing clarification on remaining aspects of the Maritime Link holdback mechanism primarily relating to release of past and future holdback amounts and requirements to end the holdback mechanism. In these decisions, the UARB agreed with the Companys submission that $12 million ($8 million related to 2022 and $4 million relating to 2023) of the previously recorded holdback remain credited to NSPIs FAM, with the remainder released to NSPML and recorded in Emeras Income from equity investments. NSPML did not record any additional holdback in Q4 2023. The UARB also confirmed that the holdback mechanism will cease once 90 per cent of NS Block deliveries are achieved for 12 consecutive months (subject to potential relief for planned outages or exceptional circumstances) and the net outstanding balance of previously underdelivered NS Block energy is less than 10 per cent of the contracted annual amount. In addition, the UARB increased the monthly holdback amount from $2 million to $4 million beginning December 1, 2023.
On December 21, 2023, NSPML received approval to collect up to $164 million (2023 $164 million) from NSPI for the recovery of costs associated with the Maritime Link in 2024; subject to a holdback of up to $4 million a month, as discussed above.
96 | EMERA 2023 ANNUAL REPORT |
Notes to the Consolidated Financial Statements
Gas Utilities and Infrastructure
PGS
PGS is regulated by the FPSC. The FPSC sets rates at a level that allows utilities such as PGS to collect total revenues or revenue requirements equal to their cost of providing service, plus an appropriate return on invested capital.
PGSs approved ROE range for 2023 and 2022 was 8.9 per cent to 11.0 per cent with a 9.9 per cent midpoint, based on an allowed equity capital structure of 54.7 per cent.
Base Rates:
On April 4, 2023, PGS filed a rate case with the FPSC and a hearing for the matter was held in September 2023. On November 9, 2023, the FPSC approved a $118 million USD increase to base revenues which includes $11 million USD transferred from the cast iron and bare steel replacement rider, for a net incremental increase to base revenues of $107 million USD. This reflects a 10.15 per cent midpoint ROE with an allowed equity capital structure of 54.7 per cent. A final order was issued on December 27, 2023, with the new rates effective January 2024.
The 2020 PGS rate case settlement provided the ability to reverse a total of $34 million USD of accumulated depreciation through 2023. PGS reversed $20 million USD of accumulated depreciation in 2023 and $14 million USD in 2022.
Fuel Recovery:
PGS recovers the costs it pays for gas supply and interstate transportation for system supply through its PGAC. 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.
Recovery of Energy Conservation and Pipeline Replacement Programs:
The FPSC annually approves a conservation charge that is intended to permit PGS to recover prudently incurred expenditures in developing and implementing cost effective energy conservation programs which are required by Florida law and approved and monitored by the FPSC. PGS also has a Cast Iron/Bare Steel Pipe Replacement clause to recover the cost of accelerating the replacement of cast iron and bare steel distribution lines in the PGS system. In February 2017, the FPSC approved expansion of the Cast Iron/Bare Steel clause to allow recovery of accelerated replacement of certain obsolete plastic pipe. The majority of cast iron and bare steel pipe has been removed from its system, with replacement of obsolete plastic pipe continuing until 2028 under the rider.
NMGC
NMGC is subject to regulation by the NMPRC. The NMPRC sets rates at a level that allows NMGC to collect total revenues equal to its cost of providing service, plus an appropriate return on invested capital.
NMGCs approved ROE for 2023 and 2022 was 9.375 per cent on an allowed equity capital structure of 52 per cent.
Base Rates:
On September 14, 2023, NMGC filed a rate case with the NMPRC for new base rates to become effective Q4 2024. NMGC requested $49 million USD in annual base revenues primarily as a result of increased operating costs and capital investments in pipeline projects and related infrastructure. The rate case includes a requested ROE of 10.5 per cent.
Fuel Recovery:
NMGC recovers gas supply costs through a PGAC. This clause recovers actual costs for purchased gas, gas storage services, interstate pipeline capacity, and other related items associated with the purchase, transmission, distribution, and sale of natural gas to its customers. On a monthly basis, NMGC can adjust charges based on the next months 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. NMGC received approval of its PGAC Continuation in December 2020, for the four-year period ending December 2024.
EMERA 2023 ANNUAL REPORT | 97 |
Notes to the Consolidated Financial Statements
Integrity Management Programs (IMP) Regulatory Asset:
A portion of NMGCs annual spending on infrastructure is for IMP, or the replacement and update of legacy systems. These programs are driven both by NMGC integrity management plans and federal and state mandates. In December 2020, NMGC received approval through its rate case to defer costs through an IMP regulatory asset for certain of its IMP capital investments occurring between January 1, 2022 and December 31, 2023 and petitioned recovery of the regulatory asset in its rate case filed on December 13, 2021. On November 30, 2022, the NMPRC issued a Final Order that included approval of recovery of the IMP regulatory asset.
Brunswick Pipeline
Brunswick Pipeline is a 145-kilometre pipeline delivering natural gas from the Saint John 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 North America Canada Partnership. The agreement provides for a predetermined toll increase in the fifth and fifteenth year of the contract. The pipeline is considered a Group II pipeline regulated by the Canada Energy Regulator (CER). The CER Gas Transportation Tariff is filed by Brunswick Pipeline in compliance with the requirements of the CER Act and sets forth the terms and conditions of the transportation rendered by Brunswick Pipeline.
Other Electric Utilities
BLPC
BLPC is regulated by the Fair Trading Commission (FTC), under the Utilities Regulation (Procedural) Rules 2003. BLPC is regulated under a cost-of-service model, with rates set to recover prudently incurred costs of providing electricity service to customers plus an appropriate return on capital invested. BLPCs approved regulated return on rate base was 10 per cent for 2023 and 2022.
Licenses:
BLPC currently operates pursuant to a single integrated license to generate, transmit and distribute electricity on the island of Barbados until 2028. In 2019, the Government of Barbados passed legislation requiring multiple licenses for the supply of electricity. In 2021, BLPC reached commercial agreement with the Government of Barbados for each of the license types, subject to the passage of implementing legislation. The timing of the final enactment is unknown at this time, but BLPC will work towards the implementation of the licenses once enacted.
Base Rates:
In 2021, BLPC submitted a general rate review application to the FTC. In September 2022, the FTC granted BLPC interim rate relief, allowing an increase in base rates of approximately $1 million USD per month. On February 15, 2023, the FTC issued a decision on the application which included the following significant items: an allowed regulatory ROE of 11.75 per cent, an equity capital structure of 55 per cent, a directive to update the major components of rate base to September 16, 2022, and a directive to establish regulatory liabilities related to the self-insurance fund of $50 million USD, prior year benefits recognized on remeasurement of deferred income taxes of $5 million USD, and accumulated depreciation of $16 million USD. On March 7, 2023, BLPC filed a Motion for Review and Variation (the Motion) and applied for a stay of the FTCs decision, which was subsequently granted. On November 20, 2023, the FTC issued their decision dismissing the Motion. Interim rates continue to be in effect through to a date to be determined in a final decision and order.
On December 1, 2023, BLPC appealed certain aspects of the FTCs February 15 and November 20, 2023, decisions to the Supreme Court of Barbados in the High Court of Justice (the Court) and requested that they be stayed. On December 11, 2023, the Court granted the stay. BLPCs position is that the FTC made errors of law and jurisdiction in their decisions and believes the success of the appeal is probable, and as a result, the adjustments to BLPCs final rates and rate base, including any adjustments to regulatory assets and liabilities, have not been recorded at this time.
98 | EMERA 2023 ANNUAL REPORT |
Notes to the Consolidated Financial Statements
Fuel Recovery:
BLPCs fuel costs flow through a fuel pass-through mechanism which provides opportunity to recover all prudently incurred fuel costs from customers in a timely manner. The calculation of the fuel charge is adjusted on a monthly basis and reported to the FTC for approval.
Clean Energy Transition Program (CETP):
On May 31, 2023, the FTC approved BLPCs application to establish an alternative cost recovery mechanism to recover prudently incurred costs associated with its CETP (the Decision). The mechanism is intended to facilitate the timely recovery between rate cases of costs associated with approved renewable energy assets. BLPC will be required to submit an individual application for the recovery of costs of each asset through the cost recovery mechanism, meeting the minimum criteria as set out in the Decision. On October 5, 2023, BLPC applied to the FTC to recover the costs of a battery storage system through the CETP.
Fuel Hedging:
On October 21, 2021, the FTC approved BLPCs application to implement a fuel hedging program which will be incorporated into the calculation of the fuel clause adjustment. On November 10, 2021, BLPC requested the FTC review the required 50/50 cost sharing arrangement between BLPC and customers in relation to the hedging administrative costs, or any gains and losses associated with the hedging program.
GBPC
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. Rates are set to recover prudently incurred costs of providing electricity service to customers plus an appropriate return on rate base. GBPCs approved regulated return on rate base was 8.32 per cent for 2023 (2022 8.23 per cent).
Base Rates:
There is a fuel pass-through mechanism and tariff review policy with new rates submitted every three years. On January 14, 2022, the GBPA issued its decision on GBPCs application for rate review that was filed with the GBPA on September 23, 2021. The decision, which became effective April 1, 2022, allows for an increase in revenues of $3.5 million USD. The rates include a regulatory ROE of 12.84 per cent.
Fuel Recovery:
GBPCs 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.
Effective November 1, 2022, GBPCs fuel pass through charge was increased due to an increase in global oil prices impacting the unhedged fuel cost. In 2023, the fuel pass through charge was adjusted monthly, in-line with actual fuel costs.
Storm Restoration Costs Hurricane Matthew:
As part of the recovery of costs incurred as a result of Hurricane Matthew, in 2016, the GBPA approved a fixed per kWh fuel charge and allowed the difference between this and the actual cost of fuel to be applied to the Hurricane Matthew regulatory asset. As part of its decision on GBPCs application for rate review, issued January 14, 2022, and effective April 1, 2022, the GBPA approved the continued amortization of the remaining regulatory asset over the three year period ending December 31, 2024.
EMERA 2023 ANNUAL REPORT | 99 |
Notes to the Consolidated Financial Statements
7. Investments Subject to Significant Influence and Equity Income
Carrying Value As at December 31 |
Equity Income December 31 |
Percentage of |
||||||||||||||||||
millions of dollars |
2023 | 2022 | 2023 | 2022 | 2023 | |||||||||||||||
LIL (1) |
$ | 747 | $ | 740 | $ | 63 | $ | 58 | 31.0 | |||||||||||
NSPML |
489 | 501 | 46 | 29 | 100.0 | |||||||||||||||
M&NP (2) |
118 | 128 | 21 | 21 | 12.9 | |||||||||||||||
Lucelec (2) |
48 | 49 | 4 | 4 | 19.5 | |||||||||||||||
Bear Swamp (3) |
| | 12 | 17 | 50.0 | |||||||||||||||
|
|
|
|
|
|
|
|
|
|
|||||||||||
$ | 1,402 | $ | 1,418 | $ | 146 | $ | 129 | |||||||||||||
|
|
|
|
|
|
|
|
(1) | Emera indirectly owns 100 per cent of the Class B units, which comprises 24.5 per cent of the total units issued. 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. Emeras 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 Emeras total investment in the Maritime Link and LIL will equal 49 per cent of the cost of all of these transmission developments. |
(2) | Emera has significant influence over the operating and financial decisions of these companies through Board representation and therefore, records its investment in these entities using the equity method. |
(3) | The investment balance in Bear Swamp is in a credit position primarily as a result of a $179 million distribution received in 2015. Bear Swamps credit investment balance of $81 million (2022 $95 million) is recorded in Other long-term liabilities on the Consolidated Balance Sheets. |
Equity investments include a $10 million difference between the cost and the underlying FV 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 32). NSPMLs consolidated summarized balance sheets are illustrated as follows:
As at millions of dollars |
December 31 2023 |
December 31 2022 |
||||||
Balance Sheets |
||||||||
Current assets |
$ | 21 | $ | 17 | ||||
PP&E |
1,473 | 1,517 | ||||||
Regulatory assets |
272 | 265 | ||||||
Non-current assets |
29 | 29 | ||||||
|
|
|
|
|||||
Total assets |
$ | 1,795 | $ | 1,828 | ||||
|
|
|
|
|||||
Current liabilities |
$ | 48 | $ | 48 | ||||
Long-term debt (1) |
1,109 | 1,149 | ||||||
Non-current liabilities |
149 | 130 | ||||||
Equity |
489 | 501 | ||||||
|
|
|
|
|||||
Total liabilities and equity |
$ | 1,795 | $ | 1,828 | ||||
|
|
|
|
(1) | The project debt has been guaranteed by the Government of Canada. |
8. Other Income, Net
For the | Year ended December 31 | |||||||
millions of dollars |
2023 | 2022 | ||||||
Interest income |
$ | 43 | $ | 25 | ||||
AFUDC |
38 | 52 | ||||||
Pension non-current service cost recovery |
35 | 24 | ||||||
FX gains (losses) |
20 | (26 | ) | |||||
TECO Guatemala Holdings award (1) |
| 63 | ||||||
Other |
22 | 7 | ||||||
|
|
|
|
|||||
$ | 158 | $ | 145 | |||||
|
|
|
|
(1) | On December 15, 2022, a payment of $63 million was made by the Republic of Guatemala to TECO Energy in satisfaction of the second and final award issued by the International Centre of the Settlement of Investment Disputes tribunal regarding a dispute over an investment in TGH, a wholly-owned subsidiary of TECO Energy. |
100 | EMERA 2023 ANNUAL REPORT |
Notes to the Consolidated Financial Statements
9. Interest Expense, Net
Interest expense, net consisted of the following:
For the | Year ended December 31 | |||||||
millions of Canadian dollars |
2023 | 2022 | ||||||
Interest on debt |
$ | 954 | $ | 727 | ||||
Allowance for borrowed funds used during construction |
(16 | ) | (21 | ) | ||||
Other |
(13 | ) | 3 | |||||
|
|
|
|
|||||
$ | 925 | $ | 709 | |||||
|
|
|
|
10. Income Taxes
The income tax provision, for the years ended December 31, differs from that computed using the enacted combined Canadian federal and provincial statutory income tax rate for the following reasons:
millions of dollars |
2023 | 2022 | ||||||
Income before provision for income taxes |
$ | 1,173 | $ | 1,194 | ||||
|
|
|
|
|||||
Statutory income tax rate |
29.0 | % | 29.0 | % | ||||
|
|
|
|
|||||
Income taxes, at statutory income tax rate |
340 | 346 | ||||||
Deferred income taxes on regulated income recorded as regulatory assets and regulatory liabilities |
(72 | ) | (70 | ) | ||||
Tax credits |
(53 | ) | (18 | ) | ||||
Foreign tax rate variance |
(36 | ) | (44 | ) | ||||
Amortization of deferred income tax regulatory liabilities |
(33 | ) | (33 | ) | ||||
Tax effect of equity earnings |
(15 | ) | (10 | ) | ||||
GBPC impairment charge |
| 21 | ||||||
Other |
(3 | ) | (7 | ) | ||||
|
|
|
|
|||||
Income tax expense |
$ | 128 | $ | 185 | ||||
|
|
|
|
|||||
Effective income tax rate |
11 | % | 15 | % | ||||
|
|
|
|
On August 16, 2022, the United States Inflation Reduction Act (IRA) was signed into legislation. The IRA includes numerous tax incentives for clean energy, such as the extension and modification of existing investment and production tax credits for projects placed in service through 2024 and introduces new technology-neutral clean energy related tax credits beginning in 2025. As of December 31, 2023, the Company has recorded a $30 million (2022 $9 million) regulatory liability on the Consolidated Balance Sheets in recognition of its obligation to pass the incremental tax benefits realized to customers.
The following table reflects the composition of taxes on income from continuing operations presented in the Consolidated Statements of Income for the years ended December 31:
millions of dollars |
2023 | 2022 | ||||||
Current income taxes |
||||||||
Canada |
$ | 26 | $ | 25 | ||||
United States |
5 | 8 | ||||||
Deferred income taxes |
||||||||
Canada |
93 | 122 | ||||||
United States |
128 | 252 | ||||||
Investment tax credits |
||||||||
United States |
(29 | ) | (7 | ) | ||||
Operating loss carryforwards |
||||||||
Canada |
(93 | ) | (94 | ) | ||||
United States |
(2 | ) | (121 | ) | ||||
|
|
|
|
|||||
Income tax expense |
$ | 128 | $ | 185 | ||||
|
|
|
|
EMERA 2023 ANNUAL REPORT | 101 |
Notes to the Consolidated Financial Statements
The following table reflects the composition of income before provision for income taxes presented in the Consolidated Statements of Income for the years ended December 31:
millions of dollars |
2023 | 2022 | ||||||
Canada |
$ | 171 | $ | 173 | ||||
United States |
964 | 1,063 | ||||||
Other |
38 | (42 | ) | |||||
|
|
|
|
|||||
Income before provision for income taxes |
$ | 1,173 | $ | 1,194 | ||||
|
|
|
|
The deferred income tax assets and liabilities presented in the Consolidated Balance Sheets as at December 31 consisted of the following:
millions of dollars |
2023 | 2022 | ||||||
Deferred income tax assets: |
||||||||
Tax loss carryforwards |
$ | 1,195 | $ | 1,207 | ||||
Tax credit carryforwards |
454 | 415 | ||||||
Derivative instruments |
205 | 45 | ||||||
Regulatory liabilities |
175 | 264 | ||||||
Other |
372 | 341 | ||||||
|
|
|
|
|||||
Total deferred income tax assets before valuation allowance |
2,401 | 2,272 | ||||||
Valuation allowance |
(363 | ) | (312 | ) | ||||
|
|
|
|
|||||
Total deferred income tax assets after valuation allowance |
$ | 2,038 | $ | 1,960 | ||||
|
|
|
|
|||||
Deferred income tax (liabilities): |
||||||||
PP&E |
$ | (3,223 | ) | $ | (2,981 | ) | ||
Derivative instruments |
(235 | ) | (125 | ) | ||||
Investments subject to significant influence |
(216 | ) | (181 | ) | ||||
Regulatory assets |
(196 | ) | (310 | ) | ||||
Other |
(312 | ) | (322 | ) | ||||
|
|
|
|
|||||
Total deferred income tax liabilities |
$ | (4,182 | ) | $ | (3,919 | ) | ||
|
|
|
|
|||||
Consolidated Balance Sheets presentation: |
||||||||
Long-term deferred income tax assets |
$ | 208 | $ | 237 | ||||
Long-term deferred income tax liabilities |
(2,352 | ) | (2,196 | ) | ||||
|
|
|
|
|||||
Net deferred income tax liabilities |
$ | (2,144 | ) | $ | (1,959 | ) | ||
|
|
|
|
Considering all evidence regarding the utilization of the Companys 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 long-term debt and investments. A valuation allowance of $363 million has been recorded as at December 31, 2023 (2022 $312 million) related to the loss carryforwards, long-term debt and investments.
The Company intends to indefinitely reinvest earnings from certain foreign operations. Accordingly, as at December 31, 2023, $4.7 billion (2022 $3.8 billion) in cumulative temporary differences for which deferred taxes might otherwise be required, have not been recognized. It is impractical to estimate the amount of income and withholding tax that might be payable if a reversal of temporary differences occurred.
102 | EMERA 2023 ANNUAL REPORT |
Notes to the Consolidated Financial Statements
Emeras NOL, capital loss and tax credit carryforwards and their expiration periods as at December 31, 2023 consisted of the following:
millions of dollars |
Tax Carryforwards |
Subject to Valuation Allowance |
Net Tax Carryforwards |
Expiration Period |
||||||||||||
Canada |
||||||||||||||||
NOL |
$ | 2,914 | $ | (1,164 | ) | $ | 1,750 | 20262043 | ||||||||
Capital loss |
73 | (73 | ) | | Indefinite | |||||||||||
United States |
||||||||||||||||
Federal NOL |
$ | 1,360 | $ | (1 | ) | $ | 1,359 | 2036Indefinite | ||||||||
State NOL |
1,003 | (1 | ) | 1,002 | 2026Indefinite | |||||||||||
Tax credit |
454 | (3 | ) | 451 | 20252043 | |||||||||||
|
|
|
|
|
|
|
|
|||||||||
Other |
||||||||||||||||
NOL |
$ | 81 | $ | (28 | ) | $ | 53 | 20242030 | ||||||||
|
|
|
|
|
|
|
|
The following table provides details of the change in unrecognized tax benefits for the years ended December 31 as follows:
millions of dollars |
2023 | 2022 | ||||||
Balance, January 1 |
$ | 33 | $ | 28 | ||||
Increases due to tax positions related to current year |
5 | 5 | ||||||
Increases due to tax positions related to a prior year |
1 | 2 | ||||||
Decreases due to tax positions related to a prior year |
(2 | ) | (2 | ) | ||||
|
|
|
|
|||||
Balance, December 31 |
$ | 37 | $ | 33 | ||||
|
|
|
|
Unrecognized tax benefits relate to the timing of certain tax deductions at NSPI and research and development tax credits primarily at TEC. The total amount of unrecognized tax benefits as at December 31, 2023 was $37 million (2022 $33 million), which would affect the effective tax rate if recognized. The total amount of accrued interest with respect to unrecognized tax benefits was $9 million (2022 $7 million) with $2 million interest expense recognized in the Consolidated Statements of Income (2022 $1 million). No penalties have been accrued. The balance of unrecognized tax benefits could change in the next 12 months as a result of resolving Canada Revenue Agency (CRA) and Internal Revenue Service audits. A reasonable estimate of any change cannot be made at this time.
During 2022, the CRA issued notices of reassessment to NSPI for the 2013 through 2016 taxation years. NSPI and the CRA are currently in a dispute with respect to the timing of certain tax deductions for its 2006 through 2010 and 2013 through 2016 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 $126 million (2022 $126 million), including interest. NSPI has prepaid $55 million of the amount in dispute, as required by CRA.
On November 29, 2019, NSPI filed a Notice of Appeal with the Tax Court of Canada with respect to its dispute of the 2006 through 2010 taxation years. 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 difference, if any, either owed to, or refunded from, the CRA. The related tax deductions will be available in subsequent years.
Should NSPI be similarly reassessed by the CRA for years not currently in dispute, further payments will be required; however, the ultimate permissibility of these deductions would be similarly not in dispute.
NSPI and its advisors believe that NSPI has reported its tax position appropriately. NSPI continues to assess its options to resolving the dispute; however, the outcome of the Notice of Appeal process is not determinable at this time.
Emera files a Canadian federal income tax return, which includes its Nova Scotia provincial income tax. Emeras subsidiaries file Canadian, US, Barbados, and St. Lucia income tax returns. As at December 31, 2023, the Companys tax years still open to examination by taxing authorities include 2005 and subsequent years.
EMERA 2023 ANNUAL REPORT | 103 |
Notes to the Consolidated Financial Statements
11. Common Stock
Authorized: Unlimited number of non-par value common shares.
2023 | 2022 | |||||||||||||||
Issued and outstanding: |
millions of shares |
millions of dollars |
millions of shares |
millions of dollars |
||||||||||||
Balance, January 1 |
269.95 | $ | 7,762 | 261.07 | $ | 7,242 | ||||||||||
Issuance of common stock under ATM program (1) (2) |
8.29 | 397 | 4.07 | 248 | ||||||||||||
Issued under the DRIP, net of discounts |
5.26 | 272 | 4.21 | 238 | ||||||||||||
Senior management stock options exercised and Employee Share Purchase Plan |
0.62 | 31 | 0.60 | 34 | ||||||||||||
|
|
|
|
|
|
|
|
|||||||||
Balance, December 31 |
284.12 | $ | 8,462 | 269.95 | $ | 7,762 | ||||||||||
|
|
|
|
|
|
|
|
(1) | For the year ended December 31, 2022, a total of 4,072,469 common shares were issued under Emeras ATM program at an average price of $61.31 per share for gross proceeds of $250 million ($248 million net of after-tax issuance costs). |
(2) | For the year ended December 31, 2023, a total of 8,287,037 common shares were issued under Emeras ATM program at an average price of $48.27 per share for gross proceeds of $400 million ($397 million net of after-tax issuance costs). |
As at December 31, 2023, the following common shares were reserved for issuance: 6 million (2022 6 million) under the senior management stock option plan, 2 million (2022 2.7 million) under the employee common share purchase plan and 18 million (2022 10 million) under the DRIP.
The issuance of common shares under the common share compensation arrangements does not allow the plans to exceed 10 per cent of Emeras outstanding common shares. As at December 31, 2023, Emera was in compliance with this requirement.
ATM EQUITY PROGRAM
On October 3, 2023, Emera filed a short form base shelf prospectus, primarily in support of the renewal of its ATM Program in Q4 2023 that will allow the Company to issue up to $600 million of common shares from treasury to the public from time to time, at the Companys discretion, at the prevailing market price. This ATM Program is expected to remain in effect until November 4, 2025.
12. Earnings Per Share
Basic earnings per share is determined by dividing net income attributable to common shareholders by the weighted average number of common shares outstanding during the period. Diluted EPS is computed by dividing net income attributable to common shareholders by the weighted average number of common shares 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 DRIP.
The following table reconciles the computation of basic and diluted earnings per share:
For the | Year ended December 31 | |||||||
millions of dollars (except per share amounts) |
2023 | 2022 | ||||||
Numerator |
||||||||
Net income attributable to common shareholders |
$ | 977.7 | $ | 945.1 | ||||
|
|
|
|
|||||
Diluted numerator |
977.7 | 945.1 | ||||||
|
|
|
|
|||||
Denominator |
||||||||
Weighted average shares of common stock outstanding basic |
273.6 | 265.5 | ||||||
Stock-based compensation |
0.2 | 0.4 | ||||||
|
|
|
|
|||||
Weighted average shares of common stock outstanding diluted |
273.8 | 265.9 | ||||||
|
|
|
|
|||||
Earnings per common share |
||||||||
Basic |
$ | 3.57 | $ | 3.56 | ||||
Diluted |
$ | 3.57 | $ | 3.55 | ||||
|
|
|
|
104 | EMERA 2023 ANNUAL REPORT |
Notes to the Consolidated Financial Statements
13. Accumulated Other Comprehensive Income
The components of AOCI are as follows:
millions of dollars |
Unrealized (loss) gain on translation of self-sustaining foreign operations |
Net change in net investment hedges |
Losses on derivatives recognized as cash flow hedges |
Net change on available- for-sale investments |
Net change in unrecognized pension and post- retirement benefit costs |
Total AOCI | ||||||||||||||||||
For the year ended December 31, 2023 |
||||||||||||||||||||||||
Balance, January 1, 2023 |
$ | 639 | $ | (62 | ) | $ | 16 | $ | (2 | ) | $ | (13 | ) | $ | 578 | |||||||||
Other comprehensive (loss) income before reclassifications |
(270 | ) | 38 | | | | (232 | ) | ||||||||||||||||
Amounts reclassified from AOCI |
| | (2 | ) | | (39 | ) | (41 | ) | |||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||||
Net current period other comprehensive (loss) income |
(270 | ) | 38 | (2 | ) | | (39 | ) | (273 | ) | ||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||||
Balance, December 31, 2023 |
$ | 369 | $ | (24 | ) | $ | 14 | $ | (2 | ) | $ | (52 | ) | $ | 305 | |||||||||
|
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|
|
|
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|
|
|
|
|
|
|||||||||||||
For the year ended December 31, 2022 |
||||||||||||||||||||||||
Balance, January 1, 2022 |
$ | 10 | $ | 35 | $ | 18 | $ | (1 | ) | $ | (37 | ) | $ | 25 | ||||||||||
Other comprehensive income (loss) before reclassifications |
629 | (97 | ) | | (1 | ) | | 531 | ||||||||||||||||
Amounts reclassified from AOCI |
| | (2 | ) | | 24 | 22 | |||||||||||||||||
|
|
|
|
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|
|
|
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|
|||||||||||||
Net current period other comprehensive income (loss) |
629 | (97 | ) | (2 | ) | (1 | ) | 24 | 553 | |||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||||
Balance, December 31, 2022 |
$ | 639 | $ | (62 | ) | $ | 16 | $ | (2 | ) | $ | (13 | ) | $ | 578 | |||||||||
|
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|
|
|
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|
|
|
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|
|
The reclassifications out of AOCI are as follows:
14. Inventory
As at millions of dollars |
December 31 2023 |
December 31 2022 |
||||||
Fuel |
$ | 382 | $ | 404 | ||||
Materials |
408 | 365 | ||||||
|
|
|
|
|||||
Total |
$ | 790 | $ | 769 | ||||
|
|
|
|
EMERA 2023 ANNUAL REPORT | 105 |
Notes to the Consolidated Financial Statements
15. Derivative Instruments
Derivative assets and liabilities relating to the foregoing categories consisted of the following:
Derivative Assets | Derivative Liabilities | |||||||||||||||
As at millions of dollars |
December 31 2023 |
December 31 2022 |
December 31 2023 |
December 31 2022 |
||||||||||||
Regulatory deferral: |
||||||||||||||||
Commodity swaps and forwards |
$ | 16 | $ | 186 | $ | 76 | $ | 42 | ||||||||
FX forwards |
3 | 18 | 3 | 1 | ||||||||||||
Physical natural gas purchases and sales |
| 52 | | | ||||||||||||
|
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|
|
|
|
|
|
|||||||||
19 | 256 | 79 | 43 | |||||||||||||
|
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|
|
|
|
|
|
|||||||||
HFT derivatives: |
||||||||||||||||
Power swaps and physical contracts |
29 | 89 | 36 | 77 | ||||||||||||
Natural gas swaps, futures, forwards, physical contracts |
319 | 340 | 531 | 1,224 | ||||||||||||
|
|
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|
|
|
|
|
|||||||||
348 | 429 | 567 | 1,301 | |||||||||||||
|
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|
|||||||||
Other derivatives: |
||||||||||||||||
Equity derivatives |
4 | | | 5 | ||||||||||||
FX forwards |
18 | 5 | 7 | 23 | ||||||||||||
|
|
|
|
|
|
|
|
|||||||||
22 | 5 | 7 | 28 | |||||||||||||
|
|
|
|
|
|
|
|
|||||||||
Total gross current derivatives |
389 | 690 | 653 | 1,372 | ||||||||||||
|
|
|
|
|
|
|
|
|||||||||
Impact of master netting agreements: |
||||||||||||||||
Regulatory deferral |
(3 | ) | (18 | ) | (3 | ) | (18 | ) | ||||||||
HFT derivatives |
(146 | ) | (276 | ) | (146 | ) | (276 | ) | ||||||||
|
|
|
|
|
|
|
|
|||||||||
Total impact of master netting agreements |
(149 | ) | (294 | ) | (149 | ) | (294 | ) | ||||||||
|
|
|
|
|
|
|
|
|||||||||
Total derivatives |
$ | 240 | $ | 396 | $ | 504 | $ | 1,078 | ||||||||
|
|
|
|
|
|
|
|
|||||||||
Current (1) |
174 | 296 | 386 | 888 | ||||||||||||
Long-term (1) |
66 | 100 | 118 | 190 | ||||||||||||
|
|
|
|
|
|
|
|
|||||||||
Total derivatives |
$ | 240 | $ | 396 | $ | 504 | $ | 1,078 | ||||||||
|
|
|
|
|
|
|
|
(1) | Derivative assets and liabilities are classified as current or long-term based upon the maturities of the underlying contracts. |
CASH FLOW HEDGES
On May 26, 2021, a treasury lock was settled for a gain of $19 million that is being amortized through interest expense over 10 years as the underlying hedged item settles.
The amounts related to cash flow hedges recorded in AOCI consisted of the following:
For the | Year ended December 31 | |||||||
millions of dollars |
2023 | 2022 | ||||||
Interest rate hedge |
Interest rate hedge |
|||||||
Realized gain in interest expense, net |
$ | 2 | $ | 2 | ||||
|
|
|
|
|||||
Total gains in net income |
$ | 2 | $ | 2 | ||||
|
|
|
|
As at millions of dollars |
December 31 2023 |
December 31 2022 |
||||||
Interest rate hedge |
Interest rate hedge |
|||||||
Total unrealized gain in AOCI - effective portion, net of tax |
$ | 14 | $ | 16 | ||||
|
|
|
|
The Company expects $2 million of unrealized gains currently in AOCI to be reclassified into net income within the next 12 months.
106 | EMERA 2023 ANNUAL REPORT |
Notes to the Consolidated Financial Statements
REGULATORY DEFERRAL
The Company has recorded the following changes with respect to derivatives receiving regulatory deferral:
millions of dollars |
Physical natural gas purchases |
Commodity swaps and forwards |
FX forwards |
Physical natural gas purchases |
Commodity swaps and forwards |
FX forwards |
||||||||||||||||||
For the year ended December 31 |
2023 | 2022 | ||||||||||||||||||||||
Unrealized gain (loss) in regulatory assets |
$ | | $ | (109 | ) | $ | (3 | ) | $ | | $ | (69 | ) | $ | 1 | |||||||||
Unrealized gain (loss) in regulatory liabilities |
(3 | ) | (73 | ) | | 28 | 343 | 16 | ||||||||||||||||
Realized (gain) loss in regulatory assets |
| (5 | ) | | | 48 | | |||||||||||||||||
Realized (gain) loss in regulatory liabilities |
| 2 | | | (41 | ) | | |||||||||||||||||
Realized (gain) loss in inventory (1) |
| 4 | (10 | ) | | (121 | ) | 1 | ||||||||||||||||
Realized (gain) in regulated fuel for generation and purchased power (2) |
(49 | ) | (9 | ) | (4 | ) | (64 | ) | (146 | ) | | |||||||||||||
Other |
| (14 | ) | | | | | |||||||||||||||||
|
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|
|
|
|
|
|
|
|
|
|
|||||||||||||
Total change derivative instruments |
$ | (52 | ) | $ | (204 | ) | $ | (17 | ) | $ | (36 | ) | $ | 14 | $ | 18 | ||||||||
|
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|
(1) | Realized (gains) losses will be recognized in fuel for generation and purchased power when the hedged item is consumed. |
(2) | Realized (gains) losses on derivative instruments settled and consumed in the period and hedging relationships that have been terminated or the hedged transaction is no longer probable. |
As at December 31, 2023, the Company had the following notional volumes designated for regulatory deferral that are expected to settle as outlined below:
millions |
2024 | 20252026 | ||||||
Physical natural gas purchases: |
||||||||
Natural gas (Mmbtu) |
7 | 6 | ||||||
|
|
|
|
|||||
Commodity swaps and forwards purchases: |
||||||||
Natural gas (Mmbtu) |
16 | 10 | ||||||
Power (MWh) |
1 | 1 | ||||||
Coal (metric tonnes) |
1 | | ||||||
|
|
|
|
|||||
FX swaps and forwards: |
||||||||
FX contracts (millions of USD) |
$ | 241 | $ | 70 | ||||
Weighted average rate |
1.3155 | 1.3197 | ||||||
% of USD requirements |
63 | % | 17 | % | ||||
|
|
|
|
HFT DERIVATIVES
The Company has recognized the following realized and unrealized gains (losses) with respect to HFT derivatives:
For the | Year ended December 31 | |||||||
millions of dollars |
2023 | 2022 | ||||||
Power swaps and physical contracts in non-regulated operating revenues |
$ | (6 | ) | $ | 17 | |||
Natural gas swaps, forwards, futures and physical contracts in non-regulated operating revenues |
1,043 | 47 | ||||||
|
|
|
|
|||||
Total gains in net income |
$ | 1,037 | $ | 64 | ||||
|
|
|
|
As at December 31, 2023, the Company had the following notional volumes of outstanding HFT derivatives that are expected to settle as outlined below:
millions |
2024 | 2025 | 2026 | 2027 | 2028 and thereafter |
|||||||||||||||
Natural gas purchases (Mmbtu) |
296 | 80 | 50 | 38 | 30 | |||||||||||||||
Natural gas sales (Mmbtu) |
338 | 86 | 16 | 6 | 4 | |||||||||||||||
Power purchases (MWh) |
1 | | | | | |||||||||||||||
Power sales (MWh) |
1 | | | | | |||||||||||||||
|
|
|
|
|
|
|
|
|
|
EMERA 2023 ANNUAL REPORT | 107 |
Notes to the Consolidated Financial Statements
OTHER DERIVATIVES
As at December 31, 2023, the Company had equity derivatives in place to manage the cash flow risk associated with forecasted future cash settlements of deferred compensation obligations and FX forwards in place to manage cash flow risk associated with forecasted USD cash inflows. The equity derivatives hedge the return on 2.9 million shares and extends until December 2024.
The FX forwards have a combined notional amount of $508 million USD and expire in 2023, 2024 and 2025.
For the | Year ended December 31 | |||||||||||||||
millions of dollars |
2023 | 2022 | ||||||||||||||
FX Forwards |
Equity Derivatives |
FX Forwards |
Equity Derivatives |
|||||||||||||
Unrealized gain (loss) in OM&G |
$ | | $ | 4 | $ | | $ | (5 | ) | |||||||
Unrealized gain (loss) in other income, net |
28 | | (18 | ) | | |||||||||||
Realized loss in OM&G |
| (13 | ) | | (17 | ) | ||||||||||
Realized loss in other income, net |
(11 | ) | | (6 | ) | | ||||||||||
|
|
|
|
|
|
|
|
|||||||||
Total gains (losses) in net income |
$ | 17 | $ | (9 | ) | $ | (24 | ) | $ | (22 | ) | |||||
|
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|
|
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|
|
|
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 counterpartys 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 Companys current default probability. Net asset positions are adjusted based on the counterpartys current default probability. The Company assesses credit risk internally for counterparties that are not rated.
As at December 31, 2023, the maximum exposure the Company had to credit risk was $1.2 billion (2022 - $1.9 billion), which included 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, FX 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, 2023 was $310 million (2022 - $386 million), which mitigated the Companys 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, North American Energy Standards Board agreements and, or Edison Electric Institute agreements. The Company believes entering into such agreements offers protection by creating contractual rights relating to creditworthiness, collateral, non-performance and default.
As at December 31, 2023, the Company had $142 million (2022 - $131 million) in financial assets, considered to be past due, which have been outstanding for an average 64 days. The FV of these financial assets was $127 million (2022 - $114 million), the difference of which was included in the allowance for credit losses. These assets primarily relate to accounts receivable from electric and gas revenue.
108 | EMERA 2023 ANNUAL REPORT |
Notes to the Consolidated Financial Statements
CONCENTRATION RISK
The Companys concentrations of risk consisted of the following:
As at |
December 31, 2023 | December 31, 2022 | ||||||||||||||
millions of dollars |
% of total exposure |
millions of dollars |
% of total exposure |
|||||||||||||
Receivables, net |
||||||||||||||||
Regulated utilities: |
||||||||||||||||
Residential |
$ | 476 | 31 | % | $ | 455 | 19 | % | ||||||||
Commercial |
194 | 13 | % | 192 | 8 | % | ||||||||||
Industrial |
84 | 5 | % | 121 | 5 | % | ||||||||||
Other |
103 | 7 | % | 122 | 5 | % | ||||||||||
Cash collateral |
94 | 6 | % | | 0 | % | ||||||||||
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|
|
|
|
|
|||||||||
951 | 62 | % | 890 | 37 | % | |||||||||||
|
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|
|
|||||||||
Trading group: |
||||||||||||||||
Credit rating of A- or above |
47 | 3 | % | 125 | 5 | % | ||||||||||
Credit rating of BBB- to BBB+ |
33 | 2 | % | 75 | 3 | % | ||||||||||
Not rated |
108 | 7 | % | 307 | 13 | % | ||||||||||
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|
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|
|||||||||
188 | 12 | % | 507 | 21 | % | |||||||||||
|
|
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|
|
|
|
|
|||||||||
Other accounts receivable |
151 | 10 | % | 585 | 25 | % | ||||||||||
|
|
|
|
|
|
|
|
|||||||||
1,290 | 84 | % | 1,982 | 83 | % | |||||||||||
|
|
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|
|
|
|||||||||
Derivative Instruments (current and long-term) |
||||||||||||||||
Credit rating of A- or above |
138 | 9 | % | 202 | 9 | % | ||||||||||
Credit rating of BBB- to BBB+ |
7 | 1 | % | 8 | 0 | % | ||||||||||
Not rated |
95 | 6 | % | 186 | 8 | % | ||||||||||
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|
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|
|||||||||
240 | 16 | % | 396 | 17 | % | |||||||||||
|
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|
|
|||||||||
$ | 1,530 | 100 | % | $ | 2,378 | 100 | % | |||||||||
|
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|
|
CASH COLLATERAL
The Companys cash collateral positions consisted of the following:
As at millions of dollars |
December 31 2023 |
December 31 2022 |
||||||
Cash collateral provided to others |
$ | 101 | $ | 224 | ||||
Cash collateral received from others |
$ | 22 | $ | 112 | ||||
|
|
|
|
Collateral is posted in the normal course of business based on the Companys 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, 2023, the total FV of derivatives in a liability position was $504 million (December 31, 2022 - $1,078 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.
16. FV Measurements
The Company is required to determine the FV of all derivatives except those which qualify for the NPNS exemption (see note 1) and uses a market approach to do so. The three levels of the FV 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.
EMERA 2023 ANNUAL REPORT | 109 |
Notes to the Consolidated Financial Statements
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 FV measurement.
The following tables set out the classification of the methodology used by the Company to FV its derivatives:
As at | December 31, 2023 | |||||||||||||||
millions of dollars |
Level 1 | Level 2 | Level 3 | Total | ||||||||||||
Assets |
||||||||||||||||
Regulatory deferral: |
||||||||||||||||
Commodity swaps and forwards |
$ | 7 | $ | 6 | $ | | $ | 13 | ||||||||
FX forwards |
| 3 | | 3 | ||||||||||||
|
|
|
|
|
|
|
|
|||||||||
7 | 9 | | 16 | |||||||||||||
|
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|
|
|
|
|||||||||
HFT derivatives: |
||||||||||||||||
Power swaps and physical contracts |
(5 | ) | 23 | | 18 | |||||||||||
Natural gas swaps, futures, forwards, physical contracts and related transportation |
42 | 108 | 34 | 184 | ||||||||||||
|
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|
|
|
|
|
|||||||||
37 | 131 | 34 | 202 | |||||||||||||
|
|
|
|
|
|
|
|
|||||||||
Other derivatives: |
||||||||||||||||
FX forwards |
| 18 | | 18 | ||||||||||||
Equity derivatives |
4 | | | 4 | ||||||||||||
|
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|
|
|
|
|
|
|||||||||
4 | 18 | | 22 | |||||||||||||
|
|
|
|
|
|
|
|
|||||||||
Total assets |
48 | 158 | 34 | 240 | ||||||||||||
|
|
|
|
|
|
|
|
|||||||||
Liabilities |
||||||||||||||||
Regulatory deferral: |
||||||||||||||||
Commodity swaps and forwards |
43 | 30 | | 73 | ||||||||||||
FX forwards |
| 3 | | 3 | ||||||||||||
|
|
|
|
|
|
|
|
|||||||||
43 | 33 | | 76 | |||||||||||||
|
|
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|
|
|
|
|
|||||||||
HFT derivatives: |
||||||||||||||||
Power swaps and physical contracts |
| 24 | | 24 | ||||||||||||
Natural gas swaps, futures, forwards and physical contracts |
13 | 19 | 365 | 397 | ||||||||||||
|
|
|
|
|
|
|
|
|||||||||
13 | 43 | 365 | 421 | |||||||||||||
|
|
|
|
|
|
|
|
|||||||||
Other derivatives: |
||||||||||||||||
FX forwards |
| 7 | | 7 | ||||||||||||
|
|
|
|
|
|
|
|
|||||||||
| 7 | | 7 | |||||||||||||
|
|
|
|
|
|
|
|
|||||||||
Total liabilities |
56 | 83 | 365 | 504 | ||||||||||||
|
|
|
|
|
|
|
|
|||||||||
Net assets (liabilities) |
$ | (8 | ) | $ | 75 | $ | (331 | ) | $ | (264 | ) | |||||
|
|
|
|
|
|
|
|
110 | EMERA 2023 ANNUAL REPORT |
Notes to the Consolidated Financial Statements
As at | December 31, 2022 | |||||||||||||||
millions of dollars |
Level 1 | Level 2 | Level 3 | Total | ||||||||||||
Assets |
||||||||||||||||
Regulatory deferral: |
||||||||||||||||
Commodity swaps and forwards |
$ | 120 | $ | 48 | $ | | $ | 168 | ||||||||
FX forwards |
| 18 | | 18 | ||||||||||||
Physical natural gas purchases and sales |
| | 52 | 52 | ||||||||||||
|
|
|
|
|
|
|
|
|||||||||
120 | 66 | 52 | 238 | |||||||||||||
|
|
|
|
|
|
|
|
|||||||||
HFT derivatives: |
||||||||||||||||
Power swaps and physical contracts |
9 | 31 | 4 | 44 | ||||||||||||
Natural gas swaps, futures, forwards, physical contracts and related transportation |
3 | 72 | 34 | 109 | ||||||||||||
|
|
|
|
|
|
|
|
|||||||||
12 | 103 | 38 | 153 | |||||||||||||
|
|
|
|
|
|
|
|
|||||||||
Other derivatives: |
||||||||||||||||
FX forwards |
| 5 | | 5 | ||||||||||||
|
|
|
|
|
|
|
|
|||||||||
Total assets |
132 | 174 | 90 | 396 | ||||||||||||
|
|
|
|
|
|
|
|
|||||||||
Liabilities |
||||||||||||||||
Regulatory deferral: |
||||||||||||||||
Commodity swaps and forwards |
15 | 9 | | 24 | ||||||||||||
FX forwards |
| 1 | | 1 | ||||||||||||
|
|
|
|
|
|
|
|
|||||||||
15 | 10 | | 25 | |||||||||||||
|
|
|
|
|
|
|
|
|||||||||
HFT derivatives: |
||||||||||||||||
Power swaps and physical contracts |
2 | 28 | 1 | 31 | ||||||||||||
Natural gas swaps, futures, forwards and physical contracts |
51 | 118 | 825 | 994 | ||||||||||||
|
|
|
|
|
|
|
|
|||||||||
53 | 146 | 826 | 1,025 | |||||||||||||
|
|
|
|
|
|
|
|
|||||||||
Other derivatives: |
||||||||||||||||
FX forwards |
| 23 | | 23 | ||||||||||||
Equity derivatives |
5 | | | 5 | ||||||||||||
|
|
|
|
|
|
|
|
|||||||||
Total liabilities |
73 | 179 | 826 | 1,078 | ||||||||||||
|
|
|
|
|
|
|
|
|||||||||
Net assets (liabilities) |
$ | 59 | $ | (5 | ) | $ | (736 | ) | $ | (682 | ) | |||||
|
|
|
|
|
|
|
|
The change in the FV of the Level 3 financial assets for the year ended December 31, 2023 was as follows:
Regulatory Deferral |
HFT Derivatives | |||||||||||||||
millions of dollars |
Physical natural gas purchases |
Power | Natural gas | Total | ||||||||||||
Balance, January 1, 2023 |
$ | 52 | $ | 4 | $ | 34 | $ | 90 | ||||||||
Realized gains (losses) included in fuel for generation and purchased power |
(49 | ) | | | (49 | ) | ||||||||||
Unrealized gains (losses) included in regulatory assets and liabilities |
(3 | ) | | | (3 | ) | ||||||||||
Total realized and unrealized gains (losses) included in non-regulated operating revenues |
| (4 | ) | | (4 | ) | ||||||||||
|
|
|
|
|
|
|
|
|||||||||
Balance, December 31, 2023 |
$ | | $ | | $ | 34 | $ | 34 | ||||||||
|
|
|
|
|
|
|
|
The change in the FV of the Level 3 financial liabilities for the year ended December 31, 2023 was as follows:
HFT Derivatives | ||||||||||||
millions of dollars |
Power | Natural gas | Total | |||||||||
Balance, January 1, 2023 |
$ | 1 | $ | 825 | $ | 826 | ||||||
Total realized and unrealized gains included in non-regulated operating revenues |
(1 | ) | (460 | ) | (461 | ) | ||||||
|
|
|
|
|
|
|||||||
Balance, December 31, 2023 |
$ | | $ | 365 | $ | 365 | ||||||
|
|
|
|
|
|
EMERA 2023 ANNUAL REPORT | 111 |
Notes to the Consolidated Financial Statements
Significant unobservable inputs used in the FV measurement of Emeras natural gas and power derivatives include third-party sourced pricing for instruments based on illiquid markets. Significant increases (decreases) in any of these inputs in isolation would result in a significantly lower (higher) FV measurement. Other unobservable inputs used include internally developed correlation factors and basis differentials; own credit risk; and discount rates. Internally developed correlations and basis differentials are reviewed on a quarterly basis based on statistical analysis of the spot markets in the various illiquid term markets. Discount rates may include a risk premium for those long-term forward contracts with illiquid future price points to incorporate the inherent uncertainty of these points. Any risk premiums for long-term contracts are evaluated by observing similar industry practices and in discussion with industry peers.
The Company uses a modelled pricing valuation technique for determining the FV of Level 3 derivative instruments. The following table outlines quantitative information about the significant unobservable inputs used in the FV measurements categorized within Level 3 of the FV hierarchy:
millions of dollars |
FV | Significant Unobservable Input |
Low | High | Weighted average (1) |
|||||||||||||||||||
Assets | Liabilities | |||||||||||||||||||||||
As at December 31, 2023 |
||||||||||||||||||||||||
HFT derivatives Natural gas swaps, futures, forwards and physical contracts |
34 | 365 | Third-party pricing | $ | 1.27 | $ | 16.25 | $ | 4.85 | |||||||||||||||
|
|
|
|
|
|
|
|
|
|
|||||||||||||||
Total |
$ | 34 | $ | 365 | ||||||||||||||||||||
|
|
|
|
|||||||||||||||||||||
Net liability |
$ | 331 | ||||||||||||||||||||||
|
|
|||||||||||||||||||||||
As at December 31, 2022 |
||||||||||||||||||||||||
Regulatory deferral Physical natural gas purchases |
$ | 52 | $ | | Third-party pricing | $ | 5.79 | $ | 31.85 | $ | 12.27 | |||||||||||||
|
|
|
|
|
|
|
|
|
|
|||||||||||||||
HFT derivatives Power swaps and physical contracts |
4 | 1 | Third-party pricing | $ | 43.24 | $ | 269.10 | $ | 138.79 | |||||||||||||||
|
|
|
|
|
|
|
|
|
|
|||||||||||||||
HFT derivatives Natural gas swaps, futures, forwards and physical contracts |
34 | 825 | Third-party pricing | $ | 2.45 | $ | 33.88 | $ | 12.01 | |||||||||||||||
|
|
|
|
|
|
|
|
|
|
|||||||||||||||
Total |
$ | 90 | $ | 826 | ||||||||||||||||||||
|
|
|
|
|||||||||||||||||||||
Net liability |
$ | 736 | ||||||||||||||||||||||
|
|
(1) | Unobservable inputs were weighted by the relative FV of the instruments. |
Long-term debt is a financial liability not measured at FV on the Consolidated Balance Sheets. The balance consisted of the following:
As at millions of dollars |
Carrying Amount |
FV | Level 1 | Level 2 | Level 3 | Total | ||||||||||||||||||
December 31, 2023 |
$ | 18,365 | $ | 16,621 | $ | | $ | 16,363 | $ | 258 | $ | 16,621 | ||||||||||||
December 31, 2022 |
$ | 16,318 | $ | 14,670 | $ | | $ | 14,284 | $ | 386 | $ | 14,670 |
The Company has designated $1.2 billion USD denominated Hybrid Notes as a hedge of the foreign currency exposure of its net investment in USD denominated operations. The Companys Hybrid Notes are contingently convertible into preferred shares in the event of bankruptcy or other related events. A redemption option on or after June 15, 2026 is available and at the control of the Company. The Hybrid Notes are classified as Level 2 financial assets. As at December 31, 2023, the FV of the Hybrid Notes was $1.2 billion (2022 $1.1 billion). An after-tax foreign currency gain of $38 million was recorded in AOCI for the year ended December 31, 2023 (2022 $97 million after-tax loss).
112 | EMERA 2023 ANNUAL REPORT |
Notes to the Consolidated Financial Statements
17. Related Party Transactions
In the ordinary course of business, Emera provides energy 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. NSPIs expense is reported in Regulated fuel for generation and purchased power, totalling $163 million for the year ended December 31, 2023 (2022 $157 million). NSPML is accounted for as an equity investment, and therefore 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 $14 million for the year ended December 31, 2023 (2022 $9 million). |
There were no significant receivables or payables between Emera and its associated companies reported on Emeras Consolidated Balance Sheets as at December 31, 2023 and at December 31, 2022.
18. Receivables and Other Current Assets
As at millions of dollars |
December 31 2023 |
December 31 2022 |
||||||
Customer accounts receivable billed |
$ | 805 | $ | 1,096 | ||||
Capitalized transportation capacity (1) |
358 | 781 | ||||||
Customer accounts receivable unbilled |
363 | 424 | ||||||
Prepaid expenses |
105 | 82 | ||||||
Income tax receivable |
10 | 9 | ||||||
Allowance for credit losses |
(15 | ) | (17 | ) | ||||
NMGC gas hedge settlement receivable (2) |
| 162 | ||||||
Other |
191 | 360 | ||||||
|
|
|
|
|||||
Total receivables and other current assets |
$ | 1,817 | $ | 2,897 | ||||
|
|
|
|
(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. |
(2) | Offsetting amount is included in regulatory liabilities for NMGC as gas hedges are part of the PGAC. For more information, refer to note 6. |
EMERA 2023 ANNUAL REPORT | 113 |
Notes to the Consolidated Financial Statements
19. Leases
LESSEE
The Company has operating leases for buildings, land, telecommunication services, and rail cars. Emeras leases have remaining lease terms of 1 year to 62 years, some of which include options to extend the leases for up to 65 years. These options are included as part of the lease term when it is considered reasonably certain they will be exercised.
As at millions of dollars |
Classification |
December 31 2023 |
December 31 2022 |
|||||||
Right-of-use asset |
Other long-term assets | $ | 54 | $ | 58 | |||||
Lease liabilities |
||||||||||
Current |
Other current liabilities | 3 | 3 | |||||||
Long-term |
Other long-term liabilities | 55 | 59 | |||||||
|
|
|
|
|||||||
Total lease liabilities |
$ | 58 | $ | 62 | ||||||
|
|
|
|
The Company recorded lease expense of $127 million for the year ended December 31, 2023 (2022 - $138 million), of which $119 million (2022 - $131 million) related to variable costs for power generation facility finance leases, recorded in Regulated fuel for generation and purchased power in the Consolidated Statements of Income.
Future minimum lease payments under non-cancellable operating leases for each of the next five years and in aggregate thereafter are as follows:
millions of dollars |
2024 | 2025 | 2026 | 2027 | 2028 | Thereafter | Total | |||||||||||||||||||||
Minimum lease payments |
$ | 6 | $ | 5 | $ | 3 | $ | 3 | $ | 3 | $ | 111 | $ | 131 | ||||||||||||||
Less imputed interest |
(73 | ) | ||||||||||||||||||||||||||
|
|
|||||||||||||||||||||||||||
Total |
$ | 58 | ||||||||||||||||||||||||||
|
|
Additional information related to Emeras leases is as follows:
Year ended December 31 | ||||||||
For the |
2023 | 2022 | ||||||
Cash paid for amounts included in the measurement of lease liabilities: |
||||||||
Operating cash flows for operating leases (millions of dollars) |
$ | 8 | $ | 8 | ||||
Right-of-use assets obtained in exchange for lease obligations: |
||||||||
Operating leases (millions of dollars) |
$ | 1 | $ | 1 | ||||
Weighted average remaining lease term (years) |
44 | 44 | ||||||
|
|
|
|
|||||
Weighted average discount rate - operating leases |
3.93 | % | 3.98 | % | ||||
|
|
|
|
LESSOR
The Companys net investment in direct finance and sales-type leases primarily relates to Brunswick Pipeline, Seacoast, compressed natural gas (CNG) stations, a renewable natural gas (RNG) facility and heat pumps.
The Company manages its risk associated with the residual value of the Brunswick Pipeline lease through proper routine maintenance of the asset.
Customers have the option to purchase CNG station assets by paying a make-whole payment at the date of the purchase based on a targeted internal rate of return or may take possession of the CNG station asset at the end of the lease term for no cost. Customers have the option to purchase heat pumps at the end of the lease term for a nominal fee.
Commencing in October 2023, the Company leased a RNG facility to a biogas producer that is classified as a sales-type lease. The term of the facility lease is 15 years, with a nominal value purchase at the end of the term and a net investment of approximately $35 million USD.
114 | EMERA 2023 ANNUAL REPORT |
Notes to the Consolidated Financial Statements
Commencing in January 2022, the Company leased Seacoast pipeline, a 21-mile, 30-inch lateral that is classified as a sales-type lease. The term of the pipeline lateral lease is 34 years with a net investment of $100 million USD. The lessee of the pipeline lateral has renewal options for an additional 16 years. These renewal options have not been included as part of the pipeline lateral lease term as it is not reasonably certain that they will be exercised.
Direct finance and sales-type lease unearned income is recognized in income over the life of the lease using a constant rate of interest equal to the internal rate of return on the lease and is recorded as Operating revenues - regulated gas and Other income, net on the Consolidated Statements of Income.
The total net investment in direct finance and sales-type leases consist of the following:
As at millions of dollars |
December 31 2023 |
December 31 2022 |
||||||
Total minimum lease payment to be received |
$ | 1,360 | $ | 1,393 | ||||
Less: amounts representing estimated executory costs |
(190 | ) | (205 | ) | ||||
|
|
|
|
|||||
Minimum lease payments receivable |
$ | 1,170 | $ | 1,188 | ||||
Estimated residual value of leased property (unguaranteed) |
183 | 183 | ||||||
Less: Credit loss reserve |
(2 | ) | | |||||
Less: unearned finance lease income |
(693 | ) | (733 | ) | ||||
|
|
|
|
|||||
Net investment in direct finance and sales-type leases |
$ | 658 | $ | 638 | ||||
|
|
|
|
|||||
Principal due within one year (included in Receivables and other current assets) |
37 | 34 | ||||||
|
|
|
|
|||||
Net Investment in direct finance and sales type leases - long-term |
$ | 621 | $ | 604 | ||||
|
|
|
|
As at December 31, 2023, future minimum lease payments to be received for each of the next five years and in aggregate thereafter were as follows:
millions of dollars |
2024 | 2025 | 2026 | 2027 | 2028 | Thereafter | Total | |||||||||||||||||||||
Minimum lease payments to be received |
$ | 97 | $ | 99 | $ | 98 | $ | 97 | $ | 96 | $ | 873 | $ | 1,360 | ||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||||||
Less: executory costs |
(190 | ) | ||||||||||||||||||||||||||
|
|
|||||||||||||||||||||||||||
Total |
$ | 1,170 | ||||||||||||||||||||||||||
|
|
20. Property, Plant and Equipment
PP&E consisted of the following regulated and non-regulated assets:
As at millions of dollars |
Estimated useful life | December 31 2023 |
December 31 2022 |
|||||||||
Generation |
3 to 131 | $ | 13,500 | $ | 13,083 | |||||||
Transmission |
10 to 80 | 2,835 | 2,731 | |||||||||
Distribution |
4 to 80 | 7,417 | 6,978 | |||||||||
Gas transmission and distribution |
6 to 92 | 5,536 | 5,061 | |||||||||
General plant and other (1) |
2 to 71 | 2,985 | 2,723 | |||||||||
|
|
|
|
|||||||||
Total cost |
32,273 | 30,576 | ||||||||||
Less: Accumulated depreciation (1) |
(9,994 | ) | (9,574 | ) | ||||||||
|
|
|
|
|||||||||
22,279 | 21,002 | |||||||||||
Construction work in progress (1) |
2,097 | 1,994 | ||||||||||
|
|
|
|
|||||||||
Net book value |
$ | 24,376 | $ | 22,996 | ||||||||
|
|
|
|
(1) | SeaCoast owns a 50% undivided ownership interest in a jointly owned 26-mile pipeline lateral located in Florida, which went into service in 2020. At December 31, 2023, SeaCoasts share of plant in service was $27 million USD (2022 - $27 million USD), and accumulated depreciation of $2 million USD (2022 - $1 million USD). SeaCoasts undivided ownership interest is financed with its funds and all operations are accounted for as if such participating interest were a wholly owned facility. SeaCoasts share of direct expenses of the jointly owned pipeline is included in OM&G in the Consolidated Statements of Income. |
EMERA 2023 ANNUAL REPORT | 115 |
Notes to the Consolidated Financial Statements
21. Employee Benefit Plans
Emera maintains a number of contributory defined-benefit (DB) and defined-contribution (DC) pension plans, which cover substantially all of its employees. In addition, the Company provides non-pension benefits for its retirees. These plans cover employees in Nova Scotia, New Brunswick, Newfoundland and Labrador, Florida, New Mexico, Barbados, and Grand Bahama Island.
Emeras net periodic benefit cost included the following:
BENEFIT OBLIGATION AND PLAN ASSETS
The changes in benefit obligation and plan assets, and the funded status for all plans were as follows:
For the | Year ended December 31 | |||||||||||||||
millions of dollars |
2023 | 2022 | ||||||||||||||
Defined benefit pension plans |
Non-pension benefit plans |
Defined benefit pension plans |
Non-pension benefit plans |
|||||||||||||
Change in Projected Benefit Obligation (PBO) and Accumulated Post-retirement Benefit Obligation (APBO) |
||||||||||||||||
Balance, January 1 |
$ | 2,158 | $ | 243 | $ | 2,624 | $ | 318 | ||||||||
Service cost |
30 | 3 | 41 | 4 | ||||||||||||
Plan participant contributions |
6 | 6 | 6 | 6 | ||||||||||||
Interest cost |
111 | 13 | 80 | 9 | ||||||||||||
Plan amendments |
| (14 | ) | | | |||||||||||
Benefits paid |
(147 | ) | (29 | ) | (174 | ) | (31 | ) | ||||||||
Actuarial losses (gains) |
146 | 10 | (480 | ) | (79 | ) | ||||||||||
Settlements and curtailments |
(8 | ) | | (6 | ) | | ||||||||||
FX translation adjustment |
(23 | ) | (5 | ) | 67 | 16 | ||||||||||
|
|
|
|
|
|
|
|
|||||||||
Balance, December 31 |
$ | 2,273 | $ | 227 | $ | 2,158 | $ | 243 | ||||||||
|
|
|
|
|
|
|
|
|||||||||
Change in plan assets |
||||||||||||||||
Balance, January 1 |
$ | 2,163 | $ | 46 | $ | 2,702 | $ | 51 | ||||||||
Employer contributions |
42 | 23 | 45 | 24 | ||||||||||||
Plan participant contributions |
6 | 6 | 6 | 6 | ||||||||||||
Benefits paid |
(147 | ) | (29 | ) | (174 | ) | (31 | ) | ||||||||
Actual return on assets, net of expenses |
262 | 3 | (489 | ) | (7 | ) | ||||||||||
Settlements and curtailments |
(8 | ) | | (6 | ) | | ||||||||||
FX translation adjustment |
(20 | ) | (1 | ) | 79 | 3 | ||||||||||
|
|
|
|
|
|
|
|
|||||||||
Balance, December 31 |
$ | 2,298 | $ | 48 | $ | 2,163 | $ | 46 | ||||||||
|
|
|
|
|
|
|
|
|||||||||
Funded status, end of year |
$ | 25 | $ | (179 | ) | $ | 5 | $ | (197 | ) | ||||||
|
|
|
|
|
|
|
|
The actuarial losses recognized in the period are primarily due to changes in the discount rate, higher than expected indexation, and compensation-related assumption changes.
PLANS WITH PBO/APBO IN EXCESS OF PLAN ASSETS
The aggregate financial position for all pension plans where the PBO or APBO (for post-retirement benefit plans) exceeded the plan assets for the years ended December 31 was as follows:
millions of dollars |
2023 | 2022 | ||||||||||||||
Defined benefit pension plans |
Non-pension benefit plans |
Defined benefit pension plans |
Non-pension benefit plans |
|||||||||||||
PBO/APBO |
$ | 120 | $ | 205 | $ | 1,006 | $ | 221 | ||||||||
FV of plan assets |
37 | | 914 | | ||||||||||||
|
|
|
|
|
|
|
|
|||||||||
Funded status |
$ | (83 | ) | $ | (205 | ) | $ | (92 | ) | $ | (221 | ) | ||||
|
|
|
|
|
|
|
|
116 | EMERA 2023 ANNUAL REPORT |
Notes to the Consolidated Financial Statements
PLANS WITH ACCUMULATED BENEFIT OBLIGATION (ABO) IN EXCESS OF PLAN ASSETS
The ABO for the DB pension plans was $2,172 million as at December 31, 2023 (2022 $2,080 million). The aggregate financial position for those plans with an ABO in excess of the plan assets for the years ended December 31 was as follows:
millions of dollars |
2023 | 2022 | ||||||
Defined benefit pension plans |
Defined benefit pension plans |
|||||||
ABO |
$ | 114 | $ | 111 | ||||
FV of plan assets |
37 | 33 | ||||||
|
|
|
|
|||||
Funded status |
$ | (77 | ) | $ | (78 | ) | ||
|
|
|
|
BALANCE SHEET
The amounts recognized in the Consolidated Balance Sheets consisted of the following:
As at millions of dollars |
December 31 2023 |
December 31 2022 |
||||||||||||||
Defined benefit pension plans |
Non-pension benefit plans |
Defined benefit pension plans |
Non-pension benefit plans |
|||||||||||||
Other current liabilities |
$ | (5 | ) | $ | (18 | ) | $ | (13 | ) | $ | (20 | ) | ||||
Long-term liabilities |
(78 | ) | (187 | ) | (80 | ) | (201 | ) | ||||||||
Other long-term assets |
108 | 26 | 98 | 24 | ||||||||||||
AOCI, net of tax and regulatory assets |
385 | 20 | 358 | 22 | ||||||||||||
Less: Deferred income tax (expense) recovery in AOCI |
(8 | ) | (1 | ) | (7 | ) | (1 | ) | ||||||||
|
|
|
|
|
|
|
|
|||||||||
Net amount recognized |
$ | 402 | $ | (160 | ) | $ | 356 | $ | (176 | ) | ||||||
|
|
|
|
|
|
|
|
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 dollars |
Regulatory assets |
Actuarial (gains) losses |
Past service (gains) costs |
|||||||||
Defined Benefit Pension Plans |
||||||||||||
Balance, January 1, 2023 |
$ | 336 | $ | 15 | $ | | ||||||
Amortized in current period |
(6 | ) | (3 | ) | | |||||||
Current year additions |
1 | 41 | | |||||||||
Change in FX rate |
(7 | ) | | | ||||||||
|
|
|
|
|
|
|||||||
Balance, December 31, 2023 |
$ | 324 | $ | 53 | $ | | ||||||
|
|
|
|
|
|
|||||||
Non-pension benefits plans |
||||||||||||
Balance, January 1, 2023 |
$ | 31 | $ | (10 | ) | $ | | |||||
Amortized in current period |
2 | 3 | | |||||||||
Current year reductions |
(3 | ) | (1 | ) | (3 | ) | ||||||
Change in FX rate |
(1 | ) | | 1 | ||||||||
|
|
|
|
|
|
|||||||
Balance, December 31, 2023 |
$ | 29 | $ | (8 | ) | $ | (2 | ) | ||||
|
|
|
|
|
|
EMERA 2023 ANNUAL REPORT | 117 |
Notes to the Consolidated Financial Statements
As at millions of dollars |
December 2023 |
December 2022 |
||||||||||||||
Defined benefit pension plans |
Non-pension benefit plans |
Defined benefit pension plans |
Non-pension benefit plans |
|||||||||||||
Actuarial losses (gains) |
$ | 53 | $ | (8 | ) | $ | 15 | $ | (10 | ) | ||||||
Past service gains |
| (2 | ) | | | |||||||||||
Deferred income tax expense |
8 | 1 | 7 | 1 | ||||||||||||
|
|
|
|
|
|
|
|
|||||||||
AOCI, net of tax |
61 | (9 | ) | 22 | (9 | ) | ||||||||||
Regulatory assets |
324 | 29 | 336 | 31 | ||||||||||||
|
|
|
|
|
|
|
|
|||||||||
AOCI, net of tax and regulatory assets |
$ | 385 | $ | 20 | $ | 358 | $ | 22 | ||||||||
|
|
|
|
|
|
|
|
BENEFIT COST COMPONENTS
Emeras net periodic benefit cost included the following:
As at | Year ended December 31 | |||||||||||||||
millions of dollars |
2023 | 2022 | ||||||||||||||
Defined benefit pension plans |
Non-pension benefit plans |
Defined benefit pension plans |
Non-pension benefit plans |
|||||||||||||
Service cost |
$ | 30 | $ | 3 | $ | 41 | $ | 4 | ||||||||
Interest cost |
111 | 13 | 80 | 9 | ||||||||||||
Expected return on plan assets |
(161 | ) | (2 | ) | (144 | ) | | |||||||||
Current year amortization of: |
||||||||||||||||
Actuarial losses (gains) |
1 | (3 | ) | 8 | | |||||||||||
Regulatory assets (liability) |
6 | (2 | ) | 21 | 2 | |||||||||||
Settlement, curtailments |
2 | | 2 | | ||||||||||||
|
|
|
|
|
|
|
|
|||||||||
Total |
$ | (11 | ) | $ | 9 | $ | 8 | $ | 15 | |||||||
|
|
|
|
|
|
|
|
The expected return on plan assets is determined based on the market-related value of plan assets of $2,577 million as at January 1, 2023 (2022 $2,482 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
Emeras 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 plans actuarial assumptions. The diversification of assets reduces the inherent risk in financial markets by requiring that assets be spread out amongst various asset classes. Within each asset class, a further diversification is undertaken through the investment in a broad range of investment and non-investment grade securities. Emeras target asset allocation is as follows:
Canadian Pension Plans
Asset class |
Target Range at Market | |||
Short-term securities |
0% to 10% | |||
Fixed income |
34% to 49% | |||
Equities: |
||||
Canadian |
7% to 17% | |||
Non-Canadian |
35% to 59% |
118 | EMERA 2023 ANNUAL REPORT |
Notes to the Consolidated Financial Statements
Non-Canadian Pension Plans
Asset class |
Target Range at Market Weighted Average |
|||
Cash and cash equivalents |
0% to 10% | |||
Fixed income |
29% to 49% | |||
Equities |
48% to 68% |
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 FV its investments:
millions of dollars |
NAV | Level 1 | Level 2 | Total | Percentage | |||||||||||||||
As at |
December 31, 2023 | |||||||||||||||||||
Cash and cash equivalents |
$ | | $ | 40 | $ | | $ | 40 | 2 | % | ||||||||||
Net in-transits |
| (9 | ) | | (9 | ) | | % | ||||||||||||
Equity securities: |
||||||||||||||||||||
Canadian equity |
| 96 | | 96 | 4 | % | ||||||||||||||
United States equity |
| 141 | | 141 | 6 | % | ||||||||||||||
Other equity |
| 112 | | 112 | 5 | % | ||||||||||||||
Fixed income securities: |
||||||||||||||||||||
Government |
| | 172 | 172 | 8 | % | ||||||||||||||
Corporate |
| | 90 | 90 | 4 | % | ||||||||||||||
Other |
| 4 | 5 | 9 | | % | ||||||||||||||
Mutual funds |
| 50 | | 50 | 2 | % | ||||||||||||||
Other |
| 6 | (1 | ) | 5 | | % | |||||||||||||
Open-ended investments measured at NAV (1) |
1,006 | | | 1,006 | 44 | % | ||||||||||||||
Common collective trusts measured at NAV (2) |
586 | | | 586 | 25 | % | ||||||||||||||
|
|
|
|
|
|
|
|
|
|
|||||||||||
Total |
$ | 1,592 | $ | 440 | $ | 266 | $ | 2,298 | 100 | % | ||||||||||
|
|
|
|
|
|
|
|
|
|
millions of dollars |
NAV | Level 1 | Level 2 | Total | Percentage | |||||||||||||||
As at |
December 31, 2022 | |||||||||||||||||||
Cash and cash equivalents |
$ | | $ | 70 | $ | | $ | 70 | 3 | % | ||||||||||
Net in-transits |
| (70 | ) | | (70 | ) | (3 | )% | ||||||||||||
Equity securities: |
||||||||||||||||||||
Canadian equity |
| 87 | | 87 | 4 | % | ||||||||||||||
United States equity |
| 233 | | 233 | 11 | % | ||||||||||||||
Other equity |
| 186 | | 186 | 8 | % | ||||||||||||||
Fixed income securities: |
||||||||||||||||||||
Government |
| | 104 | 104 | 5 | % | ||||||||||||||
Corporate |
| | 83 | 83 | 4 | % | ||||||||||||||
Other |
| 3 | 11 | 14 | 1 | % | ||||||||||||||
Mutual funds |
| 68 | | 68 | 3 | % | ||||||||||||||
Other |
| | (3 | ) | (3 | ) | | % | ||||||||||||
Open-ended investments measured at NAV (1) |
790 | | | 790 | 36 | % | ||||||||||||||
Common collective trusts measured at NAV (2) |
601 | | | 601 | 28 | % | ||||||||||||||
|
|
|
|
|
|
|
|
|
|
|||||||||||
Total |
$ | 1,391 | $ | 577 | $ | 195 | $ | 2,163 | 100 | % | ||||||||||
|
|
|
|
|
|
|
|
|
|
(1) | Net asset value (NAV) investments are open-ended registered and non-registered mutual funds, collective investment trusts, or pooled funds. NAVs are calculated at least monthly and the funds honour 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 honour subscription and redemption activity regularly. |
Refer to note 16 for more information on the FV hierarchy and inputs used to measure FV.
EMERA 2023 ANNUAL REPORT | 119 |
Notes to the Consolidated Financial Statements
POST-RETIREMENT BENEFIT PLANS
There are no assets set aside to pay for most of the Companys post-retirement benefit plans. As is common practice, post- retirement health benefits are paid from general accounts as required. The primary exception to this is the NMGC Retiree Medical Plan, which is fully funded.
INVESTMENTS IN EMERA
As at December 31, 2023 and 2022, assets related to the pension funds and post-retirement benefit plans did 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 expected cash flows for DB pension and other post-retirement benefit plans:
millions of dollars |
Defined benefit pension plans |
Non-pension benefit plans |
||||||
Expected employer contributions |
||||||||
2024 |
$ | 34 | $ | 19 | ||||
|
|
|
|
|||||
Expected benefit payments |
||||||||
2024 |
172 | 21 | ||||||
2025 |
163 | 21 | ||||||
2026 |
166 | 21 | ||||||
2027 |
171 | 21 | ||||||
2028 |
173 | 20 | ||||||
20292033 |
890 | 95 |
ASSUMPTIONS
The following table shows the assumptions that have been used in accounting for DB pension and other post-retirement benefit plans:
2023 | 2022 | |||||||||||||||
(weighted average assumptions) |
Defined benefit pension plans |
Non-pension benefit plans |
Defined benefit pension plans |
Non-pension benefit plans |
||||||||||||
Benefit obligation December 31: |
||||||||||||||||
Discount rate past service |
4.89 | % | 4.89 | % | 5.33 | % | 5.31 | % | ||||||||
Discount rate future service |
4.88 | % | 4.89 | % | 5.34 | % | 5.32 | % | ||||||||
Rate of compensation increase |
3.87 | % | 3.85 | % | 3.62 | % | 3.61 | % | ||||||||
Health care trend initial (next year) |
| 6.04 | % | | 5.40 | % | ||||||||||
ultimate |
| 3.76 | % | | 3.77 | % | ||||||||||
year ultimate reached |
2043 | 2043 | ||||||||||||||
Benefit cost for year ended December 31: |
||||||||||||||||
Discount rate past service |
5.33 | % | 5.31 | % | 3.05 | % | 2.81 | % | ||||||||
Discount rate future service |
5.34 | % | 5.32 | % | 3.18 | % | 2.92 | % | ||||||||
Expected long-term return on plan assets |
6.56 | % | 2.16 | % | 6.07 | % | 1.32 | % | ||||||||
Rate of compensation increase |
3.62 | % | 3.61 | % | 3.31 | % | 3.29 | % | ||||||||
Health care trend initial (current year) |
| 5.40 | % | | 5.09 | % | ||||||||||
ultimate |
| 3.77 | % | | 3.77 | % | ||||||||||
year ultimate reached |
2043 | 2042 |
Actual assumptions used differ by plan.
120 | EMERA 2023 ANNUAL REPORT |
Notes to the Consolidated Financial Statements
The expected long-term rate of return on plan assets is based on historical and projected real rates of return for the plans 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.
The discount rate is based on high-quality long-term corporate bonds, with maturities matching the estimated cash flows from the pension plan.
DEFINED CONTRIBUTION PLAN
Emera also provides a DC pension plan for certain employees. The Companys contribution for the year ended December 31, 2023 was $45 million (2022 $41 million).
22. Goodwill
The change in goodwill for the year ended December 31 was due to the following:
millions of dollars |
2023 | 2022 | ||||||
Balance, January 1 |
$ | 6,012 | $ | 5,696 | ||||
Change in FX rate |
(141 | ) | 389 | |||||
GBPC impairment charge |
| (73 | ) | |||||
|
|
|
|
|||||
Balance, December 31 |
$ | 5,871 | $ | 6,012 | ||||
|
|
|
|
Goodwill is subject to an annual assessment for impairment at the reporting unit level. The goodwill on Emeras Consolidated Balance Sheets at December 31, 2023, primarily related to TECO Energy (reporting units with goodwill are TEC, PGS, and NMGC).
In 2023, Emera performed qualitative impairment assessments for NMGC and PGS, concluding that the FV of the reporting units exceeded their respective carrying amounts, and as such, no quantitative assessments were performed and no impairment charges were recognized. Given the length of time passed since the last quantitative impairment test for the TEC reporting unit, Emera elected to bypass a qualitative assessment and performed a quantitative impairment assessment in Q4 2023 using a combination of the income approach and market approach. This assessment estimated that the FV of the TEC reporting unit exceeded its carrying amount, including goodwill, and as a result no impairment charges were recognized.
In 2022, the Company elected to bypass a qualitative assessment and performed a quantitative impairment assessment for GBPC, using the income approach. It was determined that the FV did not exceed its carrying amount, including goodwill. As a result of this assessment, a goodwill impairment charge of $73 million was recorded in 2022, reducing the GBPC goodwill balance to nil as at December 31, 2022. This non-cash charge is included in GBPC impairment charge on the Consolidated Statements of Income.
EMERA 2023 ANNUAL REPORT | 121 |
Notes to the Consolidated Financial Statements
23. Short-Term Debt
Emeras 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 dollars |
2023 | Weighted average interest rate |
2022 | Weighted average interest rate |
||||||||||||
TEC |
||||||||||||||||
Advances on revolving credit facilities |
$ | 277 | 5.68 | % | $ | 1,380 | 5.00 | % | ||||||||
|
|
|
|
|
|
|
|
|||||||||
Emera |
||||||||||||||||
Non-revolving term facilities |
796 | 6.07 | % | 796 | 5.19 | % | ||||||||||
Bank indebtedness |
9 | | % | | | % | ||||||||||
|
|
|
|
|
|
|
|
|||||||||
TECO Finance |
||||||||||||||||
Advances on revolving credit and term facilities |
245 | 6.54 | % | 481 | 5.47 | % | ||||||||||
|
|
|
|
|
|
|
|
|||||||||
PGS |
||||||||||||||||
Advances on revolving credit facilities |
73 | 6.36 | % | | | % | ||||||||||
|
|
|
|
|
|
|
|
|||||||||
NMGC |
||||||||||||||||
Advances on revolving credit facilities |
25 | 6.46 | % | 59 | 5.15 | % | ||||||||||
|
|
|
|
|
|
|
|
|||||||||
GBPC |
||||||||||||||||
Advances on revolving credit facilities |
8 | 5.54 | % | 10 | 5.25 | % | ||||||||||
|
|
|
|
|
|
|
|
|||||||||
Short-term debt |
$ | 1,433 | $ | 2,726 | ||||||||||||
|
|
|
|
The Companys total short-term revolving and non-revolving credit facilities, outstanding borrowings and available capacity as at December 31 were as follows:
millions of dollars |
Maturity | 2023 | 2022 | |||||||||
TEC Unsecured committed revolving credit facility |
2026 | $ | 401 | $ | 1,084 | |||||||
TECO Energy/TECO Finance revolving credit facility |
2026 | | 542 | |||||||||
TECO Finance Unsecured committed revolving credit facility |
2026 | 529 | | |||||||||
Emera Unsecured non-revolving term facility |
2024 | 400 | 400 | |||||||||
Emera Unsecured non-revolving term facility |
2024 | 400 | 400 | |||||||||
PGS Unsecured revolving credit facility |
2028 | 331 | | |||||||||
TEC Unsecured revolving facility |
2024 | 265 | 542 | |||||||||
TEC Unsecured revolving facility |
2024 | 265 | | |||||||||
NMGC Unsecured revolving credit facility |
2026 | 165 | 169 | |||||||||
Other Unsecured committed revolving credit facilities |
Various | 17 | 18 | |||||||||
|
|
|
|
|||||||||
Total |
$ | 2,773 | $ | 3,155 | ||||||||
|
|
|
|
|||||||||
Less: |
||||||||||||
Advances under revolving credit and term facilities |
1,433 | 2,731 | ||||||||||
Letters of credit issued within the credit facilities |
3 | 4 | ||||||||||
|
|
|
|
|||||||||
Total advances under available facilities |
1,436 | 2,735 | ||||||||||
|
|
|
|
|||||||||
Available capacity under existing agreements |
$ | 1,337 | $ | 420 | ||||||||
|
|
|
|
The weighted average interest rate on outstanding short-term debt at December 31, 2023 was 5.95 per cent (2022 5.01 per cent).
122 | EMERA 2023 ANNUAL REPORT |
Notes to the Consolidated Financial Statements
RECENT SIGNIFICANT FINANCING ACTIVITY BY SEGMENT
Florida Electric Utilities
On November 24, 2023, TEC repaid its $400 million USD unsecured non-revolving facility, which expired on December 13, 2023.
On April 3, 2023, TEC entered into a 364-day, $200 million USD senior unsecured revolving credit facility which matures on April 1, 2024. The credit agreement contains customary representations and warranties, events of default and financial and other covenants, and bears interest at a variable interest rate, based on either the term secured overnight financing rate (SOFR), Wells Fargos prime rate, the federal funds rate or the one-month SOFR, plus a margin.
On March 1, 2023, TEC entered into a 364-day, $200 million USD senior unsecured revolving credit facility which matures on February 28, 2024. The credit facility contains customary representations and warranties, events of default and financial and other covenants, and bears interest at a variable interest rate, based on either the term SOFR, the Bank of Nova Scotias prime rate, the federal funds rate or the one-month SOFR, plus a margin.
Gas Utilities and Infrastructure
On December 1, 2023, PGS entered into a $250 million USD senior unsecured revolving credit facility with a group of banks, maturing on December 1, 2028. PGS has the ability to request the lenders to increase their commitments under the credit facility by up to $100 million USD in the aggregate subject to agreement from participating lenders. The credit agreement contains customary representations and warranties, events of default and financial and other covenants, and bears interest at Bankers Acceptances or prime rate advances, plus a margin.
Other
On December 16, 2023, Emera amended its $400 million unsecured non-revolving facility to extend the maturity date from December 16, 2023 to December 16, 2024. There were no other changes in commercial terms from the prior agreement.
On June 30, 2023, Emera amended its $400 million unsecured non-revolving facility to extend the maturity date from August 2, 2023 to August 2, 2024. There were no other changes in commercial terms from the prior agreement.
24. Other Current Liabilities
As at millions of dollars |
December 31 2023 |
December 31 2022 |
||||||
Accrued charges |
$ | 172 | $ | 174 | ||||
Nova Scotia Cap-and-Trade Program provision (note 6) |
| 172 | ||||||
Accrued interest on long-term debt |
107 | 97 | ||||||
Pension and post-retirement liabilities (note 21) |
23 | 33 | ||||||
Sales and other taxes payable |
11 | 14 | ||||||
Income tax payable |
2 | 9 | ||||||
Other |
112 | 80 | ||||||
|
|
|
|
|||||
$ | 427 | $ | 579 | |||||
|
|
|
|
EMERA 2023 ANNUAL REPORT | 123 |
Notes to the Consolidated Financial Statements
25. Long-Term Debt
Bonds, notes and debentures are at fixed interest rates and are unsecured unless noted below. Included are certain bankers acceptances and commercial paper where the Company has the intention and the unencumbered ability to refinance the obligations for a period greater than one year.
Long-term debt as at December 31 consisted of the following:
Weighted average interest rate (1) |
||||||||||||||||||||
millions of dollars |
2023 | 2022 | Maturity | 2023 | 2022 | |||||||||||||||
Emera |
||||||||||||||||||||
Bankers acceptances, SOFR loans |
Variable | Variable | 2027 | $ | 465 | $ | 403 | |||||||||||||
Unsecured fixed rate notes |
4.84 | % | 2.90 | % | 2030 | 500 | 500 | |||||||||||||
Fixed to floating subordinated notes (USD) (2) |
6.75 | % | 6.75 | % | 2076 | 1,587 | 1,625 | |||||||||||||
|
|
|
|
|||||||||||||||||
$ | 2,552 | $ | 2,528 | |||||||||||||||||
|
|
|
|
|||||||||||||||||
Emera Finance |
||||||||||||||||||||
Unsecured senior notes |
3.65 | % | 3.65 | % | 20242046 | $ | 3,637 | $ | 3,725 | |||||||||||
|
|
|
|
|||||||||||||||||
TEC (3) |
||||||||||||||||||||
Fixed rate notes and bonds |
4.61 | % | 4.15 | % | 20242051 | $ | 5,654 | $ | 4,341 | |||||||||||
|
|
|
|
|||||||||||||||||
PGS |
||||||||||||||||||||
Fixed rate notes and bonds |
5.63 | % | 3.78 | % | 20282053 | $ | 1,223 | $ | 772 | |||||||||||
|
|
|
|
|||||||||||||||||
NMGC |
||||||||||||||||||||
Fixed rate notes and bonds |
3.78 | % | 3.11 | % | 20262051 | $ | 642 | $ | 521 | |||||||||||
Non-revolving term facility, floating rate |
Variable | Variable | 2024 | 30 | 108 | |||||||||||||||
|
|
|
|
|||||||||||||||||
$ | 672 | $ | 629 | |||||||||||||||||
|
|
|
|
|||||||||||||||||
NMGI |
||||||||||||||||||||
Fixed rate notes and bonds |
3.64 | % | 3.64 | % | 2024 | $ | 198 | $ | 203 | |||||||||||
|
|
|
|
|||||||||||||||||
NSPI |
||||||||||||||||||||
Discount Notes (4) |
Variable | Variable | 20242027 | $ | 721 | $ | 881 | |||||||||||||
Medium term fixed rate notes |
5.13 | % | 5.14 | % | 20252097 | 3,165 | 2,665 | |||||||||||||
|
|
|
|
|||||||||||||||||
$ | 3,886 | $ | 3,546 | |||||||||||||||||
|
|
|
|
|||||||||||||||||
EBP |
||||||||||||||||||||
Senior secured credit facility |
Variable | Variable | 2026 | $ | 246 | $ | 249 | |||||||||||||
|
|
|
|
|||||||||||||||||
ECI |
||||||||||||||||||||
Secured senior notes |
Variable | Variable | 2027 | $ | 75 | $ | 86 | |||||||||||||
Amortizing fixed rate notes |
4.00 | % | 3.97 | % | 2026 | 79 | 100 | |||||||||||||
Non-revolving term facility, floating rate |
Variable | Variable | 2025 | 29 | 30 | |||||||||||||||
Non-revolving term facility, fixed rate |
2.15 | % | 2.05 | % | 20252027 | 155 | 91 | |||||||||||||
Secured fixed rate senior notes (5) |
3.09 | % | 3.06 | % | 20242029 | 84 | 142 | |||||||||||||
|
|
|
|
|||||||||||||||||
$ | 422 | $ | 449 | |||||||||||||||||
|
|
|
|
|||||||||||||||||
Adjustments |
||||||||||||||||||||
Fair market value adjustment TECO Energy acquisition |
$ | | $ | 2 | ||||||||||||||||
Debt issuance costs |
(125 | ) | (126 | ) | ||||||||||||||||
Amount due within one year |
(676 | ) | (574 | ) | ||||||||||||||||
|
|
|
|
|||||||||||||||||
$ | (801 | ) | $ | (698 | ) | |||||||||||||||
|
|
|
|
|||||||||||||||||
Long-Term Debt |
$ | 17,689 | $ | 15,744 | ||||||||||||||||
|
|
|
|
(1) | Weighted average interest rate of fixed rate long-term debt. |
(2) | In 2023, the Company recognized $109 million in interest expense (2022 $110 million) related to its fixed to floating subordinated notes. |
(3) | A substantial part of TECs tangible assets are pledged as collateral to secure its first mortgage bonds. There are currently no bonds outstanding under TECs first mortgage bond indenture. |
(4) | Discount notes are backed by a revolving credit facility which matures in 2027. Bankers acceptances are issued under NSPIs non-revolving term facility which matures in 2024. NSPI has the intention and unencumbered ability to refinance bankers acceptances for a period of greater than one year. |
(5) | Notes are issued and payable in either USD or BBD. |
124 | EMERA 2023 ANNUAL REPORT |
Notes to the Consolidated Financial Statements
The Companys total long-term revolving credit facilities, outstanding borrowings and available capacity as at December 31 were as follows:
millions of dollars |
Maturity | 2023 | 2022 | |||||||||
Emera revolving credit facility (1) |
June 2027 | $ | 900 | $ | 900 | |||||||
TEC Unsecured committed revolving credit facility |
December 2026 | 657 | | |||||||||
NSPI revolving credit facility (1) |
December 2027 | 800 | 800 | |||||||||
NSPI non-revolving credit facility |
July 2024 | 400 | 400 | |||||||||
Emera Unsecured non-revolving credit facility |
February 2024 | 400 | | |||||||||
NMGC Unsecured non-revolving credit facility |
March 2024 | 30 | 108 | |||||||||
ECI revolving credit facilities |
October 2024 | 10 | 11 | |||||||||
|
|
|
|
|||||||||
Total |
$ | 3,197 | $ | 2,219 | ||||||||
|
|
|
|
|||||||||
Less: |
||||||||||||
Borrowings under credit facilities |
1,884 | 1,396 | ||||||||||
Letters of credit issued inside credit facilities |
6 | 12 | ||||||||||
|
|
|
|
|||||||||
Use of available facilities |
$ | 1,890 | $ | 1,408 | ||||||||
|
|
|
|
|||||||||
Available capacity under existing agreements |
$ | 1,307 | $ | 811 | ||||||||
|
|
|
|
(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. Emeras significant covenants are listed below:
Financial Covenant |
Requirement |
As at December 31, 2023 |
||||||
Emera |
||||||||
Syndicated credit facilities |
Debt to capital ratio | Less than or equal to 0.70 to 1 | 0.57 : 1 |
RECENT SIGNIFICANT FINANCING ACTIVITY BY SEGMENT
Florida Electric Utility
On January 30, 2024, TEC issued $500 million USD of senior unsecured bonds that bear interest at 4.90 per cent with a maturity date of March 1, 2029. Proceeds from the issuance were primarily used for repayment of short-term borrowings outstanding under the 5-year credit facility. Therefore, $497 million USD of short-term borrowings that were repaid was classified as long- term debt at December 31, 2023.
Canadian Electric Utilities
On March 24, 2023, NSPI issued $500 million in unsecured notes. The issuance included $300 million unsecured notes that bear interest at 4.95 per cent with a maturity date of November 15, 2032, and $200 million unsecured notes that bear interest at 5.36 per cent with a maturity date of March 24, 2053.
Gas Utilities and Infrastructure
On December 19, 2023, PGS completed an issuance of $925 million USD in senior notes. The issuance included $350 million USD senior notes that bear interest at 5.42 per cent with a maturity date of December 19, 2028, $350 million USD senior notes that bear interest at 5.63 per cent with a maturity date of December 19, 2033 and $225 million USD senior notes that bear interest at 5.94 per cent with a maturity date of December 19, 2053.
On October 19, 2023, NMGC issued $100 million USD in senior unsecured notes that bear interest at 6.36 per cent with a maturity date of October 19, 2033.
EMERA 2023 ANNUAL REPORT | 125 |
Notes to the Consolidated Financial Statements
Other Electric Utilities
On May 24, 2023, GBPC issued a $28 million USD non-revolving term loan that bears interest at 4.00 per cent with a maturity date of May 24, 2028.
Other
On August 18, 2023, Emera entered into a $400 million non-revolving term facility with a maturity date of February 19, 2024. The credit agreement contains customary representations and warranties, events of default and financial and other covenants, and bears interest at Bankers Acceptances or prime rate advances, plus a margin. On February 16, 2024, Emera extended the term of this agreement to a maturity date of February 19, 2025.
On May 2, 2023, Emera issued $500 million in senior unsecured notes that bear interest at 4.84 per cent with a maturity date of May 2, 2030.
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 dollars |
2024 | 2025 | 2026 | 2027 | 2028 | Thereafter | Total | |||||||||||||||||||||
Emera |
$ | 199 | $ | | $ | 1,587 | $ | 266 | $ | | $ | 500 | $ | 2,552 | ||||||||||||||
Emera US Finance LP |
397 | | 992 | | | 2,248 | 3,637 | |||||||||||||||||||||
TEC |
397 | | | | | 5,257 | 5,654 | |||||||||||||||||||||
PGS |
| | | | 463 | 760 | 1,223 | |||||||||||||||||||||
NMGC |
30 | | 93 | | | 549 | 672 | |||||||||||||||||||||
NMGI |
198 | | | | | | 198 | |||||||||||||||||||||
NSPI |
398 | 125 | 40 | 323 | | 3,000 | 3,886 | |||||||||||||||||||||
EBP |
| | 246 | | | | 246 | |||||||||||||||||||||
ECI |
51 | 139 | 89 | 77 | 62 | 4 | 422 | |||||||||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||||||
Total |
$ | 1,670 | $ | 264 | $ | 3,047 | $ | 666 | $ | 525 | $ | 12,318 | $ | 18,490 | ||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
26. Asset Retirement Obligations
AROs mostly relate to reclamation of land at the thermal, hydro and combustion turbine sites; and the disposal of polychlorinated biphenyls in transmission and distribution equipment and a pipeline site. Certain hydro, transmission and distribution assets may have additional AROs that cannot be measured as these assets are expected to be used for an indefinite period and, as a result, a reasonable estimate of the FV of any related ARO cannot be made.
The change in ARO for the years ended December 31 is as follows:
millions of dollars |
2023 | 2022 | ||||||
Balance, January 1 |
$ | 174 | $ | 174 | ||||
Accretion included in depreciation expense |
9 | 9 | ||||||
Change in FX rate |
(1 | ) | 3 | |||||
Additions |
| 1 | ||||||
Accretion deferred to regulatory asset (included in PP&E) |
18 | 1 | ||||||
Liabilities settled |
(8 | ) | (1 | ) | ||||
Revisions in estimated cash flows |
| (13 | ) | |||||
|
|
|
|
|||||
Balance, December 31 |
$ | 192 | $ | 174 | ||||
|
|
|
|
126 | EMERA 2023 ANNUAL REPORT |
Notes to the Consolidated Financial Statements
27. Commitments and Contingencies
A. COMMITMENTS
As at December 31, 2023, contractual commitments (excluding pensions and other post-retirement obligations, long-term debt and asset retirement obligations) for each of the next five years and in aggregate thereafter consisted of the following:
millions of dollars |
2024 | 2025 | 2026 | 2027 | 2028 | Thereafter | Total | |||||||||||||||||||||
Transportation (1) |
$ | 696 | $ | 495 | $ | 405 | $ | 388 | $ | 338 | $ | 2,597 | $ | 4,919 | ||||||||||||||
Purchased power (2) |
274 | 249 | 263 | 312 | 312 | 3,435 | 4,845 | |||||||||||||||||||||
Fuel, gas supply and storage |
556 | 215 | 62 | | 5 | | 838 | |||||||||||||||||||||
Capital projects |
778 | 111 | 70 | 1 | | | 960 | |||||||||||||||||||||
Equity investment commitments (3) |
240 | | | | | | 240 | |||||||||||||||||||||
Other |
154 | 147 | 56 | 46 | 35 | 221 | 659 | |||||||||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||||||
$ | 2,698 | $ | 1,217 | $ | 856 | $ | 747 | $ | 690 | $ | 6,253 | $ | 12,461 | |||||||||||||||
|
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|
|
|
|
|
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|
|
|
(1) | Purchasing commitments for transportation of fuel and transportation capacity on various pipelines. Includes a commitment of $134 million related to a gas transportation contract between PGS and SeaCoast through 2040. |
(2) | Annual requirement to purchase electricity production from IPPs or other utilities over varying contract lengths. |
(3) | Emera has a commitment to make equity contributions to the LIL related to an investment true up in 2024 and sustaining capital contributions over the life of the partnership. The commercial agreements between Emera and Nalcor require true ups to finalize the respective investment obligations of the parties in relation the Maritime Link and LIL which is expected to be approximately $240 million in 2024. In addition, Emera has future commitments to provide sustaining capital to the LIL for routine capital and major maintenance. |
NSPI has a contractual obligation to pay NSPML for use of the Maritime Link over approximately 38 years from its January 15, 2018 in-service date. In February 2022, the UARB issued its decision and Board Order approving NSPMLs requested rate base of approximately $1.8 billion. In December 2023, the UARB approved the collection of up to $164 million from NSPI for the recovery of Maritime Link costs in 2024. The timing and amounts payable to NSPML for the remainder of the 38-year commitment period are subject to UARB approval.
Construction of the LIL is complete, and the Newfoundland Electrical System Operator confirmed the asset to be operating suitably to support reliable system operation and full functionality at 700MW, which was validated by the Government of Canadas Independent Engineer issuing its Commissioning Certificate on April 13, 2023.
Emera has committed to obtain certain transmission rights for Nalcor, if requested, to enable it to transmit energy which is not otherwise used in Newfoundland and Labrador or Nova Scotia. Nalcor has the right to transmit this energy from Nova Scotia to New England energy markets effective August 15, 2021 and continuing for 50 years. As transmission rights are contracted, the obligations are included within Other in the above table.
B. LEGAL PROCEEDINGS
Superfund and Former Manufactured Gas Plant Sites
Previously, TEC had been a potentially responsible party (PRP) for certain superfund sites through its Tampa Electric and former PGS divisions, as well as for certain former manufactured gas plant sites through its PGS division. As a result of the separation of the PGS division into a separate legal entity, Peoples Gas System, Inc. is also now a PRP for those sites (in addition to third party PRPs for certain sites). While the aggregate joint and several liability associated with these sites has not changed as a result of the PGS legal separation, the sites continue to present the potential for significant response costs. As at December 31, 2023, the aggregate financial liability of the Florida utilities is estimated to be $15 million ($11 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 the Florida utilities. The estimates to perform the work are based on the Florida utilities 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.
EMERA 2023 ANNUAL REPORT | 127 |
Notes to the Consolidated Financial Statements
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, the Florida utilities could be liable for more than their 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.
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.
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 FV measurements are discussed in note 15 and note 16.
Sound risk management is an essential discipline for running the business efficiently and pursuing the Companys strategy successfully. Emera has an enterprise-wide risk management process, overseen by its Enterprise Risk Management Committee (ERMC) and monitored by the Board of Directors, to ensure an effective, consistent and coherent approach to risk management. The Board of Directors has a Risk and Sustainability Committee (RSC) with a mandate that includes oversight of the Companys Enterprise Risk Management framework, including the identification, assessment, monitoring and management of enterprise risks. It also includes oversight of the Companys approach to sustainability and its performance relative to its sustainability objectives.
Regulatory and Political Risk
The Companys rate-regulated subsidiaries and certain investments subject to significant influence are subject to risk of the recovery of costs and investments. Regulatory and political risk can include changes in regulatory frameworks, shifts in government policy, legislative changes, and regulatory decisions.
As cost-of-service utilities with an obligation to serve customers, Emeras utilities operate under formal regulatory frameworks, and must obtain regulatory approval to change or add rates and/or riders. Emera also holds investments in entities in which it has significant influence, and which are subject to regulatory and political risk including NSPML, LIL, and M&NP. As a regulated Group II pipeline, the tolls of Brunswick Pipeline are regulated by the CER on a complaint basis, as opposed to the regulatory approval process described above. In the absence of a complaint, the CER does not normally undertake a detailed examination of Brunswick Pipelines tolls, which are subject to a firm service agreement, expiring in 2034, with Repsol Energy North America Canada Partnership.
Regulators administer the regulatory frameworks covering material aspects of the utilities businesses, including applying market-based tests to determine the appropriate customer rates and/or riders, the underlying allowed ROEs, deemed capital structures, capital investment, the terms and conditions for the provision of service, performance standards, and affiliate transactions. Regulators also review the prudency of costs and other decisions that impact customer rates and reliability of service and work to ensure the financial health of the utility for the benefit of customers. Costs and investments can be recovered upon approval by the respective regulator as an adjustment to rates and/or riders, which normally require a public hearing process or may be mandated by other governmental bodies. 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. Regulatory decisions, legislative changes, and prolonged delays in the recovery of costs or regulatory assets could result in decreased rate affordability for customers and could materially affect Emera and its utilities.
128 | EMERA 2023 ANNUAL REPORT |
Notes to the Consolidated Financial Statements
Emeras utilities generally manage this risk through transparent regulatory disclosure, ongoing stakeholder and government consultation and multi-party engagement on aspects such as utility operations, regulatory audits, rate filings and capital plans. The subsidiaries work to establish collaborative relationships with regulatory stakeholders, including customer representatives, both through its approach to filings and additional efforts with technical conferences and, where appropriate, negotiated settlements.
Changes in government and shifts in government policy and legislation can impact the commercial and regulatory frameworks under which Emera and its subsidiaries operate. This includes initiatives regarding deregulation or restructuring of the energy industry. Deregulation or restructuring of the energy industry may result in increased competition and unrecovered costs that could adversely affect the Companys operations, net income and cash flows. State and local policies in some United States jurisdictions have sought to prevent or limit the ability of utilities to provide customers the choice to use natural gas while in other jurisdictions policies have been adopted to prevent limitations on the use of natural gas. Changes in applicable state or local laws and regulations, including electrification legislation, could adversely impact PGS and NMGC.
Emera cannot predict future legislative, policy, or regulatory changes, whether caused by economic, political or other factors, or its ability to respond in an effective and timely manner or the resulting compliance costs. Government interference in the regulatory process can undermine regulatory stability, predictability, and independence, and could have a material adverse effect on the Company.
Foreign Exchange Risk
The Company is exposed to foreign currency exchange rate changes. Emera operates internationally, with an increasing amount of the Companys net income earned outside of Canada. As such, Emera is exposed to movements in exchange rates between the CAD and, particularly, the USD, which could positively or adversely affect results.
Consistent with the Companys risk management policies, Emera manages currency risks through matching United States denominated debt to finance its United States operations and may use foreign currency derivative instruments to hedge specific transactions and earnings exposure. The Company may enter FX forward and swap contracts to limit exposure on certain foreign currency transactions such as fuel purchases, revenue streams and capital expenditures, and on net income earned outside of Canada. The regulatory framework for the Companys rate-regulated subsidiaries permits the recovery of prudently incurred costs, including FX.
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 Emeras ability to ensure sufficient funds are available to meet its financial obligations. Emera manages this risk by forecasting cash requirements on a continuous basis to determine whether sufficient funds are available. Liquidity and capital needs could be financed through internally generated cash flows, asset sales, short-term credit facilities, and ongoing access to capital markets.
Emeras access to capital and cost of borrowing is subject to several risk factors, including financial market conditions, market disruptions and ratings assigned by various market analysts, including 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. Emeras growth plan requires significant capital investments in PP&E and the risk associated with changes in interest rates could have an adverse effect on the cost of financing. The Companys future access to capital and cost of borrowing may be impacted by various market disruptions. The inability to access cost-effective capital could have a material impact on Emeras ability to fund its growth plan.
EMERA 2023 ANNUAL REPORT | 129 |
Notes to the Consolidated Financial Statements
Emera is subject to financial risk associated with changes in its credit ratings. There are a number of factors that rating agencies evaluate to determine credit ratings, including the Companys business, its regulatory framework and legislative environment, political interference in the regulatory process, the ability to recover costs and earn returns, diversification, leverage, liquidity and increased exposure to climate change-related impacts, including increased frequency and severity of hurricanes and other severe weather events. A decrease in a credit rating could result in higher interest rates in future financings, increased borrowing costs under certain existing credit facilities, limit access to the commercial paper market, or limit the availability of adequate credit support for subsidiary operations. For more information on interest rate risk, refer to General Economic Risk Interest Rate Risk. For certain derivative instruments, if the credit ratings of the Company were reduced below investment grade, the full value of the net liability of these positions could be required to be posted as collateral. Emera manages these risks by actively monitoring and managing key financial metrics with the objective of sustaining investment grade credit ratings.
The Company has exposure to its own common share price through the issuance of various forms of stock-based compensation, which affect earnings through revaluation of the outstanding units every period. The Company uses equity derivatives to reduce the earnings volatility derived from stock-based compensation.
General Economic Risk
The Company has exposure to the macro-economic conditions in North America and in other geographic regions in which Emera operates. Like most utilities, economic factors such as consumer income, employment and housing affect demand for electricity and natural gas, and in turn the Companys financial results. Adverse changes in general economic conditions and inflation may impact the ability of customers to afford rate increases arising from increases to fuel, operating, capital, environmental compliance, and other costs, and therefore could materially affect Emera and its utilities. This may also result in higher credit and counterparty risk, adverse shifts in government policy and legislation, and/or increased risk to full and timely recovery of costs and regulatory assets.
Interest Rate Risk:
Emera utilizes a combination of fixed and floating rate debt financing for operations and capital expenditures, resulting in an exposure to interest rate risk. Emera seeks to manage interest rate risk through a portfolio approach that includes the use of fixed and floating rate debt with staggered maturities. The Company will, from time to time, issue long-term debt or enter interest rate hedging contracts to limit its exposure to fluctuations in floating interest rate debt.
For Emeras 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 ROEs 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.
Interest rates could also be impacted by changes in credit ratings. For more information, refer to Liquidity and Capital Market Risk.
As with most other utilities and other similar yield-returning investments, Emeras share price may be affected by changes in interest rates and could underperform the market in an environment of rising interest rates.
Inflation Risk:
The Company may be exposed to changes in inflation that may result in increased operating and maintenance costs, capital investment, and fuel costs compared to the revenues provided by customer rates. Emeras utilities have budgeting and forecasting processes to identify inflationary risk factors and measure operating performance, as well as collective bargaining agreements that mitigate the short-term impact of inflation on labour costs of unionized employees.
Commodity Price Risk
The Companys utility fuel supply and purchase of other commodities is subject to commodity price risk. In addition, Emera Energy is subject to commodity price risk through its portfolio of commodity contracts and arrangements.
130 | EMERA 2023 ANNUAL REPORT |
Notes to the Consolidated Financial Statements
The Company manages this risk through established processes and practices to identify, monitor, report and mitigate these risks. These include the Companys commercial arrangements, such as the combination of supply and purchase agreements, asset management agreements, pipeline transportation agreements and financial hedging instruments. In addition, its credit policies, counterparty credit assessments, market and credit position reporting, and other risk management and reporting practices, are also used to manage and mitigate this risk.
Regulated Utilities:
The Companys utility fuel supply is exposed to broader global conditions, which may include impacts on delivery reliability and price, despite contracted terms. Supply and demand dynamics in fuel markets can be affected by a wide range of factors which are difficult to predict and may change rapidly, including but not limited to currency fluctuations, changes in global economic conditions, natural disasters, transportation or production disruptions, and geo-political risks such as political instability, conflicts, changes to international trade agreements, trade sanctions or embargos. The Company seeks to manage this risk using financial hedging instruments and physical contracts and through contractual protection with counterparties, where applicable.
The majority of Emeras regulated electric and gas utilities have adopted and implemented fuel adjustment mechanisms and purchased gas adjustment mechanisms respectively, which further helps manage commodity price risk, as the regulatory framework for the Companys rate-regulated subsidiaries permits the recovery of prudently incurred fuel and gas costs. There is no assurance that such mechanisms and regulatory frameworks will continue to exist in the future. Prolonged and substantial increases in fuel prices could result in decreased rate affordability, increased risk of recovery of costs or regulatory assets, and/or negative impacts on customer consumption patterns and sales.
Emera Energy Marketing and Trading:
Emera Energy has employed further measures to manage commodity risk. The majority of Emera Energys 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. Changes in commodity prices can also result in increased collateral requirements associated with physical contracts and financial hedges, resulting in higher liquidity requirements and increased costs to the business.
To measure commodity price risk exposure, Emera Energy employs a number of controls and processes, including an estimated VaR analysis of its exposures. The VaR amount represents an estimate of the potential change in FV that could occur from changes in Emera Energys portfolio or changes in market factors within a given confidence level, if an instrument or portfolio is held for a specified time period. The VaR calculation is used to quantify exposure to market risk associated with physical commodities, primarily natural gas and power positions.
Income Tax Risk
The computation of the Companys 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 Companys future earnings, cash flows, and financial position. The value of Emeras existing deferred income 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 Companys tax compliance filings and financial results.
D. GUARANTEES AND LETTERS OF CREDIT
Emera has guarantees and letters of credit on behalf of third parties outstanding. The following significant guarantees and letters of credit are not included within the Consolidated Balance Sheets as at December 31, 2023:
TECO Energy has issued a guarantee in connection with SeaCoasts 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 was terminated on January 1, 2022. In the event that TECO Energys and Emeras long-term senior unsecured credit ratings are downgraded below investment grade by Moodys Investor Services (Moodys) or S&P Global Ratings (S&P). TECO Energy would be required to provide its counterparty a letter of credit or cash deposit of $27 million USD.
EMERA 2023 ANNUAL REPORT | 131 |
Notes to the Consolidated Financial Statements
TECO Energy issued a guarantee in connection with SeaCoasts performance obligations under a firm service agreement, which expires on December 31, 2055, subject to two extension terms at the option of the counterparty with a final expiration date of December 31, 2071. The guarantee is for a maximum potential amount of $13 million USD if SeaCoast fails to pay or perform under the firm service agreement. In the event that TECO Energys long-term senior unsecured credit ratings are downgraded below investment grade by Moodys or S&P, TECO Energy would need to provide either a substitute guarantee from an affiliate with an investment grade credit rating or a letter of credit or cash deposit of $13 million USD.
Emera Inc. has issued a guarantee of $66 million USD relating to outstanding notes of ECI. This guarantee will automatically terminate on the date upon which the obligations have been repaid in full.
NSPI has issued guarantees on behalf of its subsidiary, NS Power Energy Marketing Incorporated, in the amount of $104 million USD (2022 $119 million USD) with terms of varying lengths.
The Company has standby letters of credit and surety bonds in the amount of $103 million USD (December 31, 2022 $145 million USD) to third parties that have extended credit to Emera and its subsidiaries. These letters of credit and surety bonds typically have a one-year term and are renewed annually as required.
Emera Inc., on behalf of NSPI, has a standby letter of credit to secure obligations under a supplementary retirement plan. The expiry date of this letter of credit was extended to June 2024. The amount committed as at December 31, 2023 was $56 million (December 31, 2022 $63 million).
Collaborative Arrangements
For the years ended December 31, 2023 and 2022, 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 partys project assets by the total project assets. NSPI has power purchase arrangements to purchase the entire net output of the projects and, therefore, NSPIs portion of the revenues are recorded net within regulated fuel for generation and purchased power. NSPIs portion of operating expenses is recorded in OM&G on the Consolidated Statements of Income. In 2023, NSPI recognized $8 million net expense (2022 $12 million) in Regulated fuel for generation and purchased power and $3 million (2022 $3 million) in OM&G on the Consolidated Statements of Income.
28. Cumulative Preferred Stock
Authorized:
Unlimited number of First Preferred shares, issuable in series. Unlimited number of Second Preferred shares, issuable in series.
December 31, 2023 | December 31, 2022 | |||||||||||||||||||||||
Annual Dividend per Share |
Redemption Price per Share |
Issued and Outstanding |
Net Proceeds |
Issued and Outstanding |
Net Proceeds |
|||||||||||||||||||
Series A |
$ | 0.5456 | $ | 25.00 | 4,866,814 | $ | 119 | 4,866,814 | $ | 119 | ||||||||||||||
Series B |
Floating | $ | 25.00 | 1,133,186 | $ | 28 | 1,133,186 | $ | 28 | |||||||||||||||
Series C |
$ | 1.6085 | $ | 25.00 | 10,000,000 | $ | 245 | 10,000,000 | $ | 245 | ||||||||||||||
Series E |
$ | 1.1250 | $ | 25.00 | 5,000,000 | $ | 122 | 5,000,000 | $ | 122 | ||||||||||||||
Series F |
$ | 1.0505 | $ | 25.00 | 8,000,000 | $ | 195 | 8,000,000 | $ | 195 | ||||||||||||||
Series H |
$ | 1.5810 | $ | 25.00 | 12,000,000 | $ | 295 | 12,000,000 | $ | 295 | ||||||||||||||
Series J |
$ | 1.0625 | $ | 25.00 | 8,000,000 | $ | 196 | 8,000,000 | $ | 196 | ||||||||||||||
Series L |
$ | 1.1500 | $ | 26.00 | 9,000,000 | $ | 222 | 9,000,000 | $ | 222 | ||||||||||||||
|
|
|
|
|
|
|
|
|||||||||||||||||
Total |
58,000,000 | $ | 1,422 | 58,000,000 | $ | 1,422 | ||||||||||||||||||
|
|
|
|
|
|
|
|
132 | EMERA 2023 ANNUAL REPORT |
Notes to the Consolidated Financial Statements
Characteristics of the First Preferred Shares:
First Preferred Shares (1) (2) |
Initial Yield (%) |
Current Annual Dividend ($) |
Minimum Reset Dividend Yield (%) |
Earliest Redemption Option Date |
Redemption Value ($) |
Right to Convert on a one for one basis |
||||||||||||||||
Fixed rate reset (3) (4) |
||||||||||||||||||||||
Series A |
4.400 | 0.5456 | 1.84 | August 15, 2025 | 25.00 | Series B | ||||||||||||||||
Series C (5) (6) |
4.100 | 1.6085 | 2.65 | August 15, 2028 | 25.00 | Series D | ||||||||||||||||
Series F |
4.202 | 1.0505 | 2.63 | February 15, 2025 | 25.00 | Series G | ||||||||||||||||
Minimum rate reset (3) (4) |
||||||||||||||||||||||
Series B |
2.393 | Floating | 1.84 | August 15, 2025 | 25.00 | Series A | ||||||||||||||||
Series H (5) (7) |
4.900 | 1.5810 | 4.90 | August 15, 2028 | 25.00 | Series I | ||||||||||||||||
Series J |
4.250 | 1.0625 | 4.25 | May 15, 2026 | 25.00 | Series K | ||||||||||||||||
Perpetual fixed rate |
||||||||||||||||||||||
Series E (8) |
4.500 | 1.1250 | 25.00 | |||||||||||||||||||
Series L (9) |
4.600 | 1.1500 | November 15, 2026 | 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, 2028, February 15, 2025 and August 15, 2028, 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) | On July 6, 2023, Emera announced it would not redeem the outstanding Preferred Shares, Series C and Series H on August 15, 2023. On August 4, 2023, Emera announced after having taken into account all conversion notices received from holders, no Series C Shares were converted into Series D Shares and no Series H Shares were converted into Series I shares. |
(6) | The annual fixed dividend per share for Series C Shares was reset from $1.1802 to $1.6085 for the five-year period from and including August 15, 2028. |
(7) | The annual fixed dividend per share for Series H Shares was reset from $1.2250 to $1.5810 for the five-year period from and including August 15, 2028. |
(8) | First Preferred Shares, Series E are redeemable at $25.00 per share. |
(9) | First Preferred Shares, Series L are redeemable at $26.00 on or after November 15, 2026 to November 15, 2027, decreasing $0.25 each year until November 15, 2030 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 are deducted on the Consolidated Statements of Income before arriving at Net income attributable to common shareholders and shown on the Consolidated Statement of Changes in Equity as a deduction from retained earnings.
The First Preferred Shares of each series rank on a parity with the First Preferred Shares of every other series and are entitled to a preference over the Second Preferred Shares, the Common Shares, and any other shares ranking junior to the First Preferred Shares with respect to the payment of dividends and the distribution of the remaining property and assets or return of capital of the Company in the liquidation, dissolution or wind-up, whether voluntary or involuntary.
In the event the Company fails to pay, in aggregate, eight quarterly dividends on any series of the First Preferred Shares, the holders of the First Preferred Shares, for only so long as the dividends remain in arrears, will be entitled to attend any meeting of shareholders of the Company at which directors are to be elected and to vote for the election of two directors out of the total number of directors elected at any such meeting.
29. Non-Controlling Interest in Subsidiaries
As at millions of dollars |
December 31 2023 |
December 31 2022 |
||||||
Preferred shares of GBPC |
$ | 14 | $ | 14 | ||||
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|
|
|
|||||
$ | 14 | $ | 14 | |||||
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|
EMERA 2023 ANNUAL REPORT | 133 |
Notes to the Consolidated Financial Statements
PREFERRED SHARES OF GBPC:
Authorized:
10,000 non-voting cumulative redeemable variable perpetual preferred shares.
2023 | 2022 | |||||||||||||||
Issued and outstanding: |
number of shares |
millions of dollars |
number of shares |
millions of dollars |
||||||||||||
Outstanding as at December 31 |
10,000 | $ | 14 | 10,000 | $ | 14 |
GBPC NONVOTING CUMULATIVE VARIABLE PERPETUAL PREFERRED STOCK:
The preferred shares are redeemable by GBPC after June 17, 2021, at $1,000 Bahamian per share plus accrued and unpaid dividends and are entitled to a 6.0 per cent per annum fixed cumulative preferential dividend to be paid semi-annually.
The Preferred Shares rank behind GBPCs current and future secured and unsecured debt and ahead of all of GBPCs current and future common stock.
30. Supplementary Information to Consolidated Statements of Cash Flows
For the | Year ended December 31 | |||||||
millions of dollars |
2023 | 2022 | ||||||
Changes in non-cash working capital: |
||||||||
Inventory |
$ | (31 | ) | $ | (214 | ) | ||
Receivables and other current assets (1) |
653 | (636 | ) | |||||
Accounts payable |
(538 | ) | 423 | |||||
Other current liabilities (2) |
(179 | ) | 193 | |||||
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|
|
|
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Total non-cash working capital |
$ | (95 | ) | $ | (234 | ) | ||
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|
|
(1) | Includes $162 million related to the January 2023 settlement of NMGC gas hedges (2022 ($162) million). Offsetting regulatory liability is included in operating cash flow before working capital resulting in no impact to net cash provided by operating activities. |
(2) | Includes ($166) million related to the Nova Scotia Cap-and-Trade program (2022 $172 million). For further detail, refer to note 6. Offsetting regulatory asset (FAM) balance is included in operating cash flow before working capital resulting in no impact to net cash provided by operating activities. |
For the | Year ended December 31 | |||||||
millions of dollars |
2023 | 2022 | ||||||
Supplemental disclosure of cash paid: |
||||||||
Interest |
$ | 930 | $ | 699 | ||||
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|
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|
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Income taxes |
$ | 43 | $ | 67 | ||||
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Supplemental disclosure of non-cash activities: |
||||||||
Common share dividends reinvested |
$ | 271 | $ | 237 | ||||
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Decrease in accrued capital expenditures |
$ | (19 | ) | $ | (13 | ) | ||
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Reclassification of short-term debt to long-term debt |
657 | | ||||||
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Reclassification of long-term debt to short-term debt |
$ | | $ | 500 | ||||
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Supplemental disclosure of operating activities: |
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Net change in short-term regulatory assets and liabilities |
$ | 123 | $ | (157 | ) | |||
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31. Stock-Based Compensation
EMPLOYEE COMMON SHARE PURCHASE PLAN AND COMMON SHAREHOLDERS DIVIDEND REINVESTMENT AND SHARE PURCHASE PLAN
Eligible employees may participate in the ECSPP. As of December 31, 2023, the plan allows employees to make cash contributions of a minimum of $25 to a maximum of $20,000 CAD or $15,000 USD per year for the purpose of purchasing common shares of Emera. The Company also contributes 20 per cent of the employees contributions to the plan.
134 | EMERA 2023 ANNUAL REPORT |
Notes to the Consolidated Financial Statements
The plan allows reinvestment of dividends for all participants except where prohibited by law. The maximum aggregate number of Emera common shares reserved for issuance under this plan is 7 million common shares. As at December 31, 2023, Emera was in compliance with this requirement.
Compensation cost for shares issued under the ECSPP for the year ended December 31, 2023 was $3 million (2022 $3 million) and was included in OM&G on the Consolidated Statements of Income.
The Company also has a Common Shareholders DRIP, which provides an opportunity for shareholders residing in Canada to reinvest dividends and purchase common shares. This plan provides for a discount of up to 5 per cent from the average market price of Emeras common shares for common shares purchased in connection with the reinvestment of cash dividends. The discount was 2 per cent in 2023.
STOCK-BASED COMPENSATION PLANS
Stock Option Plan
The Company has a stock option plan that grants options to senior management of the Company for a maximum term of 10 years. The option price of the stock options is the closing price of the Companys common shares on the Toronto Stock Exchange on the last business day on which such shares were traded before the date on which the option is granted. The maximum aggregate number of shares issuable under this plan is 14.7 million shares. As at December 31, 2023, Emera was in compliance with this requirement.
Stock options granted in 2021 and prior vest in 25 per cent increments on the first, second, third and fourth anniversaries of the date of the grant. Stock options granted in 2022 and thereafter vest in 20 per cent increments on the first, second, third, fourth and fifth anniversaries of the date of the grant. If an option is not exercised within 10 years, it expires and the optionee loses all rights thereunder. The holder of the option has no rights as a shareholder until the option is exercised and shares have been issued. The total number of stocks to be optioned to any optionee shall not exceed five per cent of the issued and outstanding common stocks on the date the option is granted.
For stock options granted in 2021 and prior, unless a stock option has expired, vested options may be exercised within the 27 months following the option holders date of retirement, six months following a termination without just cause or death, and within sixty days following the date of termination for just cause or resignation. Commencing with the 2022 stock option grant, vested options may be exercised during the full term of the option following the option holders date of retirement, six months following a termination without just cause or death, and within sixty days following the date of termination for just cause or resignation. 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 FV per stock option along with the assumptions incorporated into the valuation models for options granted, for the year-ended December 31:
2023 | 2022 | |||||||
Weighted average FV per option |
$ | 6.32 | $ | 5.35 | ||||
Expected term (1) |
5 years | 5 years | ||||||
Risk-free interest rate (2) |
3.53 | % | 1.79 | % | ||||
Expected dividend yield (3) |
5.05 | % | 4.55 | % | ||||
Expected volatility (4) |
20.07 | % | 18.87 | % |
(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. |
EMERA 2023 ANNUAL REPORT | 135 |
Notes to the Consolidated Financial Statements
The following table summarizes stock option information for 2023:
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, 2022 |
2,853,879 | $ | 50.41 | 1,348,400 | $ | 4.08 | ||||||||||
Granted |
483,100 | 54.64 | 483,100 | 6.32 | ||||||||||||
Exercised |
(146,475 | ) | 43.94 | N/A | N/A | |||||||||||
Forfeited |
(94,900 | ) | 56.32 | (51,625 | ) | 3.61 | ||||||||||
Vested |
N/A | N/A | (526,620 | ) | 3.58 | |||||||||||
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Options outstanding December 31, 2023 |
3,095,604 | $ | 51.20 | 1,253,255 | $ | 5.17 | ||||||||||
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Options exercisable December 31, 2023 (2) (3) |
1,842,349 | $ | 48.39 | |||||||||||||
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(1) | As at December 31, 2023, 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 3 years (2022 $4 million, 3 years). |
(2) | As at December 31, 2023, the weighted average remaining term of vested options was 5 years with an aggregate intrinsic value of $8 million (2022 5 years, $10 million). |
(3) | As at December 31, 2023, the FV of options that vested in the year was $2 million (2022 $2 million). |
Compensation cost recognized for stock options for the year ended December 31, 2023 was $2 million (2022 $2 million), which was included in OM&G on the Consolidated Statements of Income.
As at December 31, 2023, cash received from option exercises was $6 million (2022 $9 million). The total intrinsic value of options exercised for the year ended December 31, 2023 was $2 million (2022 $4 million). The range of exercise prices for the options outstanding as at December 31, 2023 was $32.35 to $60.03 (2022 $32.35 to $60.03).
SHARE UNIT PLANS
The Company has DSU, PSU and RSU plans. The plans and the liabilities are marked-to-market at the end of each period based on an average common share price at the end of the period.
Deferred Share Unit Plans
Under the Directors DSU plan, Directors of the Company may elect to receive all or any portion of their compensation in DSUs in lieu of cash compensation, subject to requirements to receive a minimum portion of their annual retainer in DSUs. Directors fees are paid on a quarterly basis and, at the time of each payment of fees, the applicable amount is converted to DSUs. A DSU has a value equal to one Emera common share. When a dividend is paid on Emeras common shares, the Directors DSU account is credited with additional DSUs. DSUs cannot be redeemed for cash until the Director retires, resigns or otherwise leaves the Board. The cash redemption value of a DSU equals the market value of a common share at the time of redemption, pursuant to the plan. Following retirement or resignation from the Board, the value of the DSUs credited to the participants account is calculated by multiplying the number of DSUs in the participants account by Emeras closing common share price on the date DSUs are redeemed.
Under the executive and senior management DSU plan, each participant may elect to defer all or a percentage of their annual incentive award in the form of DSUs with the understanding, for participants who are subject to executive share ownership guidelines, a minimum of 50 per cent of the value of their actual annual incentive award (25 per cent in the first year of the program) will be payable in DSUs until the applicable guidelines are met.
When short-term 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 Emeras common shares, each participants 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 participants account is calculated by multiplying the number of DSUs in the participants account by the average of Emeras stock closing price for the fifty trading days prior to a given calculation date. Payments are made in cash.
In addition, special DSU awards may be made from time to time by the Management Resources and Compensation Committee (MRCC), to selected executives and senior management to recognize singular achievements or by achieving certain corporate objectives.
136 | EMERA 2023 ANNUAL REPORT |
Notes to the Consolidated Financial Statements
A summary of the activity related to employee and director DSUs for the year ended December 31, 2023 is presented in the following table:
Employee DSU |
Weighted Average Grant Date FV |
Director DSU |
Weighted Average Grant Date FV |
|||||||||||||
Outstanding as at December 31, 2022 |
627,223 | $ | 41.55 | 664,258 | $ | 45.83 | ||||||||||
Granted including DRIP |
85,740 | 47.66 | 117,893 | 49.99 | ||||||||||||
Exercised |
N/A | N/A | (53,093 | ) | 49.39 | |||||||||||
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Outstanding and exercisable as at December 31, 2023 |
712,963 | $ | 42.29 | 729,058 | $ | 46.24 | ||||||||||
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Compensation cost recovery recognized for employee and director DSUs for the year ended December 31, 2023 was $2 million (2022 $6 million). Tax expense related to this compensation cost recovery for share units realized for the year ended December 31, 2023 was $1 million (2022 $2 million). The aggregate intrinsic value of the outstanding shares for the year ended December 31, 2023 for employees was $36 million (2022 $33 million). The aggregate intrinsic value of the outstanding shares for the year ended December 31, 2023 for directors was $37 million (2022 $34 million). Cash payments made during the year ended December 31, 2023 associated with the DSU plan were $3 million (2022 $8 million).
Performance Share Unit Plan
Under the PSU plan, certain executive and senior employees are eligible for long-term incentives payable through the plan. PSUs are granted annually for three-year overlapping performance cycles, resulting in a cash payment. PSUs are granted based on the average of Emeras stock closing price for the fifty trading days prior to the effective grant date. Dividend equivalents are awarded and paid in the form of additional PSUs. The PSU value varies according to the Emera common share market price and corporate performance.
PSUs vest at the end of the three-year cycle and the payouts will be calculated and approved by the MRCC early in the following year. The value of the payout considers actual service over the performance cycle and may be pro-rated in certain departure scenarios. In the case of retirement, as defined in the PSU plan, grants may continue to vest in full and payout in normal course post-retirement.
A summary of the activity related to employee PSUs for the year ended December 31, 2023 is presented in the following table:
Employee PSU |
Weighted Average Grant Date FV |
Aggregate intrinsic value |
||||||||||
Outstanding as at December 31, 2022 |
690,446 | $ | 56.24 | $ | 40 | |||||||
Granted including DRIP |
386,261 | 52.71 | ||||||||||
Exercised |
(323,155 | ) | 54.62 | |||||||||
Forfeited |
(10,187 | ) | 55.15 | |||||||||
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Outstanding as at December 31, 2023 |
743,365 | $ | 55.13 | $ | 41 | |||||||
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Compensation cost recognized for the PSU plan for the year ended December 31, 2023 was $11 million (2022 $18 million). Tax benefits related to this compensation cost for share units realized for the year ended December 31, 2023 were $3 million (2022 $5 million). Cash payments made during the year ended December 31, 2023 associated with the PSU plan were $19 million (2022 $24 million).
Restricted Share Unit Plan
Under the RSU plan, certain executive and senior employees are eligible for long-term incentives payable through the plan. RSUs are granted annually for three-year overlapping performance cycles, resulting in a cash payment. RSUs are granted based on the average of Emeras stock closing price for the fifty trading days prior to the effective grant date. Dividend equivalents are awarded and paid in the form of additional RSUs. The RSU value varies according to the Emera common share market price.
RSUs vest at the end of the three-year cycle and the payouts will be calculated and approved by the MRCC early in the following year. The value of the payout considers actual service over the performance cycle and may be pro-rated in certain departure scenarios. In the case of retirement, as defined in the RSU plan, grants may continue to vest in full and payout in normal course post-retirement.
EMERA 2023 ANNUAL REPORT | 137 |
Notes to the Consolidated Financial Statements
A summary of the activity related to employee RSUs for the year ended December 31, 2023 is presented in the following table:
Employee RSU |
Weighted Average Grant Date FV |
Aggregate intrinsic value |
||||||||||
Outstanding as at December 31, 2022 |
508,468 | $ | 56.25 | $ | 30 | |||||||
Granted including DRIP |
236,537 | 52.07 | ||||||||||
Exercised |
(171,537 | ) | 54.62 | |||||||||
Forfeited |
(10,827 | ) | 54.76 | |||||||||
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Outstanding as at December 31, 2023 |
562,641 | $ | 55.01 | $ | 32 | |||||||
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Compensation cost recognized for the RSU plan for the year ended December 31, 2023 was $10 million (2022 $9 million). Tax benefits related to this compensation cost for share units realized for the year ended December 31, 2023 were $3 million (2022 $2 million). Cash payments made during the year ended December 31, 2023 associated with the RSU plan were $10 million (2022 nil).
32. Variable Interest Entities
Emera holds a variable interest in NSPML, a VIE for which it was determined that Emera is not the primary beneficiary since it does not have the controlling financial interest of NSPML. When the critical milestones were achieved, Nalcor Energy was deemed the primary beneficiary of the asset for financial reporting purposes as it has authority over the majority of the direct activities that are expected to most significantly impact the economic performance of the Maritime Link. Thus, Emera began recording the Maritime Link as an equity investment.
BLPC has established a 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 ECIs subsidiary BLPC and BLPC, alone, obtains the benefits from the SIFs 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. Emeras consolidated VIE in the SIF is recorded as Other long-term assets, Restricted cash and Regulatory liabilities on the Consolidated Balance Sheets. Amounts included in restricted cash represent the cash portion of funds required to be set aside for the BLPC SIF.
The Company has identified certain long-term purchase power agreements that meet the definition of variable interests as the Company has to purchase all or a majority of the electricity generation at a fixed price. However, it was determined that the Company was not the primary beneficiary since it lacked the power to direct the activities of the entity, including the ability to operate the generating facilities and make management decisions.
The following table provides information about Emeras portion of material unconsolidated VIEs:
As at |
December 31, 2023 | December 31, 2022 | ||||||||||||||
millions of dollars |
Total assets | Maximum exposure to loss |
Total assets | Maximum exposure to loss |
||||||||||||
Unconsolidated VIEs in which Emera has variable interests |
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NSPML (equity accounted) |
$ | 489 | $ | 6 | $ | 501 | $ | 6 |
33. Subsequent Events
These financial statements and notes reflect the Companys evaluation of events occurring subsequent to the balance sheet date through February 26, 2024, the date the financial statements were issued.
138 | EMERA 2023 ANNUAL REPORT |
Emera Leadership and Board
As of March 31, 2024
Emera Leadership
Scott Balfour
President and
Chief Executive Officer,
Emera Inc.
Mike Barrett
Executive Vice President, Legal and General Counsel,
Emera Inc.
Greg Blunden
Chief Financial Officer,
Emera Inc.
Archie Collins
President and Chief Executive Officer, Tampa Electric
Peter Gregg
President and Chief Executive Officer, Nova Scotia Power
Karen Hutt
Executive Vice President, Business Development and Strategy,
Emera Inc.
Bruce Marchand
Chief Risk and Sustainability Officer,
Emera Inc.
Dan Muldoon
Executive Vice President, Project Development and Operations Support,
Emera Inc.
Michael Roberts
Chief Human Resources Officer, Emera Inc.
Ryan Shell
President,
New Mexico Gas Company
Judy Steele
President and
Chief Operating Officer,
Emera Energy
Helen Wesley
President,
Peoples Gas
Board of Directors
Jackie Sheppard
Chair, Emera Board of Directors
Calgary, Alberta
Scott Balfour
President and
Chief Executive Officer Halifax, Nova Scotia
James Bertram
Calgary, Alberta
Henry Demone
Lunenburg, Nova Scotia
Paula Gold-Williams
San Antonio, Texas
Kent Harvey
New York, New York
Lynn Loewen
Westmount, Quebec
Brian Porter
Toronto, Ontario
Ian Robertson
Oakville, Ontario
Andrea Rosen
Toronto, Ontario
Karen Sheriff
Picton, Ontario
Jochen Tilk
Toronto, Ontario
EMERA 2023 ANNUAL REPORT | 139 |
Shareholder Information
For general inquiries, please contact our corporate office:
Emera Inc.
P.O. Box 910
Halifax, Nova Scotia B3J 2W5
T: 902.450.0507 or 1.888.450.0507
Information regarding Company news and initiatives, including our 2023 Annual Report, is available on our website: www.emera.com
Transfer Agent
TSX Trust Company
P.O. Box 2082, Station C
Halifax, Nova Scotia B3J 3B7
T: 1.877.982.8762
F: 1.888.249.6189
www.tsxtrust.com
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
Dave Bezanson
Vice President, Investor Relations and Pensions
T: 902.474.2126
E: dave.bezanson@emera.com
Arianne Amirkhalkhali
Senior Manager, Investor Relations
T: 902.425.8130
E: arianne.amirkhalkhali@emera.com
This Annual Report contains forward-looking information. Actual future results may differ materially. Additional financial and operational information is filed electronically with various securities commissions in Canada, copies of which are available electronically under Emeras profile on SEDAR+ at www.sedarplus.ca.
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,
EMA.PR.H, EMA.PR.J and EMA.PR.L
Barbados Stock Exchange (BSE) Depositary receipts: EMABDR Bahamas International Securities
Exchange (BISX)
Depositary receipts: EMAB
Shares Outstanding
Common shares: 284,117,511
(as of December 31, 2023)
Dividends Paid in 2023
Emera Inc. paid common share dividends of $0.69 per quarter in Q1, Q2 and Q3 (annualized rate of $2.76 per common share) and $0.7175 in Q4 (annualized rate of $2.87 per common share), for an effective annual common share dividend rate of $2.7875 per common share.
Dividend Payments in 2024
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 $0.7175, a Series A First Preferred Share dividend of $0.1364, a Series B First Preferred Share dividend of $0.4408, a Series C First Preferred Share dividend of $0.40213, a Series E First Preferred Share dividend of $0.28125, a Series F First Preferred Share dividend of $0.26263, a Series H First Preferred Share dividend of $0.39525, a Series J First Preferred Share dividend of $0.265625 and a Series L First Preferred Share dividend of $0.2875 were declared and paid on February 15, 2024.
Dividend Reinvestment and Share Purchase Plan
Emeras Dividend Reinvestment and Share Purchase Plan is available to shareholders who reside in Canada. The plan provides a convenient and economical means of acquiring additional common shares through the reinvestment of dividends with a discount of up to five per cent. In 2023, the discount was two per cent. Plan participants may also contribute cash payments of up to $5,000 per quarter. Plan participants pay no commissions, service charges or brokerage fees for shares purchased under the plan. Please contact Investor Services if you have questions or wish to receive an enrollment form.
Direct Deposit Service
Registered shareholders may have dividends deposited directly to any bank account in Canada. To arrange this service, please contact TSX Trust Company. Beneficial shareholders should contact their financial intermediary.
Quarterly Earnings
Quarterly earnings are expected to be announced in May, August and November 2024. Year-end results for 2024 will be released in February 2025.
Emera is represented in the TSX Composite, TSX Capped Utilities, TSX60 and select MSCI and FTSE World indexes.
140 | EMERA 2023 ANNUAL REPORT |
Our Operating Companies As of December 31, 2023 TAMPA ELECTRIC Vertically integrated electric utility serving about 840,000 customers in west central Florida. NOVA SCOTIA POWER Vertically integrated electric utility serving approximately 549,000 customers in Nova Scotia. PEOPLES GAS Natural gas utility serving 490,000 customers in Florida. NEW MEXICO GAS Natural gas utility serving 540,000 customers in New Mexico. EMERA CARIBBEAN Vertically integrated electric utilities serving more than 150,000 customers on the islands of Barbados and Grand Bahama. EMERA NEWFOUNDLAND & LABRADOR Owns and operates the Maritime Link and manages Emeras investment in an associated project. EMERA ENERGY Energy marketing and trading, asset management and optimization in Canada and the US. EMERA NEW BRUNSWICK Owns and operates the Brunswick pipeline, a 145-kilometre natural gas pipeline in New Brunswick. BLOCK ENERGY A technology company focused on finding new, innovative ways to deliver renewable and resilient energy to customers. www.emera.com
www.emera.com
Exhibit 99.3
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Form of Proxy - Emera Incorporated
Annual Shareholders Meeting of May 23, 2024
Appointment of Proxyholder
I/We, being holder(s) of Emera Incorporated (the Company) common shares, hereby appoint: M. Jacqueline Sheppard, or failing her, Scott C. Balfour, or failing him, Brian C. Curry, OR
[Print the name of the person you are appointing if this person is someone other than the individuals listed above.]
as proxy of the undersigned, to participate, act and vote on behalf of the undersigned in accordance with the below direction (or if no directions have been given, as the proxy sees fit) on all of the following matters and any other matter that may properly come before the Annual Meeting of Shareholders of the Company to be held at 2:00 p.m. Atlantic time on Thursday, May 23, 2024, virtually at: https://web.lumiagm.com/407390256, using password: emera2024 (case sensitive) (the Meeting), and at any and all adjournments or postponements thereof in the same manner, to the same extent and with the same powers as if the undersigned were personally present, with full power of substitution.
Management recommends voting FOR Resolutions 1, 2, 3 and 4. Please use a dark black pencil or pen.
1. | Election of Directors | FOR | WITHHOLD | FOR | WITHHOLD | |||||||
01. Scott C. Balfour |
☐ | ☐ | 07. Brian J. Porter |
☐ | ☐ | |||||||
02. James V. Bertram |
☐ | ☐ | 08. Ian E. Robertson |
☐ | ☐ | |||||||
03. Henry E. Demone |
☐ | ☐ | 09. M. Jacqueline Sheppard |
☐ | ☐ | |||||||
04. Paula Y. Gold-Williams |
☐ | ☐ | 10. Karen H. Sheriff |
☐ | ☐ | |||||||
05. Kent M. Harvey |
☐ | ☐ | 11. Jochen E. Tilk |
☐ | ☐ | |||||||
06. B. Lynn Loewen |
☐ | ☐ | ||||||||||
2. | Appointment of Auditors | FOR | WITHHOLD | |||||||||
Appointment of Ernst & Young LLP as auditors | ☐ | ☐ | ||||||||||
3. | Authorize Remuneration of Auditors | FOR | AGAINST | |||||||||
Authorize the directors to fix the remuneration of the Auditors 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 Emeras 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 Managements 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.
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Signature(s) | Date |
Please sign exactly as your name(s) appears on this proxy. Please see reverse for instructions. All proxies must be received by 5:00 p.m. Atlantic time, Tuesday, May 21, 2024 or if the meeting is adjourned or postponed, by 5:00 p.m. Atlantic time two business days prior to the reconvened meeting date.
Under Canadian Securities Law, you are entitled to receive certain investor documents. Electronic financial statements and MD&A are available at www.emera.com and at www.sedarplus.com. If you wish to receive copies, please tick the box below or go to the website https://services.tsxtrust.com/financialstatements and input code 1705a.
❑ | I would like to receive interim financial statements and MD&A. |
❑ | I would like to receive annual financial statements and MD&A. |
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Form of Proxy - Emera Incorporated
Annual Shareholders Meeting of May 23, 2024
1. | Every shareholder has the right to appoint some other person or company of the shareholders choice, who need not be a shareholder of Emera Incorporated, as that shareholders proxyholder to participate, act and vote on the shareholders behalf at the meeting or any adjournment or postponement thereof. If you wish to appoint a person or company other than the persons whose names are printed herein, please insert the name of your chosen proxyholder in the space provided on the reverse and return your proxy by mail, fax or email. In addition, to enable your chosen proxyholder to participate and vote virtually at the Meeting, YOU MUST contact TSX Trust Company TSX either by calling 1-866-751-6315 (toll-free within North America) or 1-416-682-3860 (outside North America) or by logging onto the TSX website at: https://www.tsxtrust.com/control-number-request, by 5:00 p.m. Atlantic time on May 21, 2024 or if the meeting is adjourned or postponed, by 5:00 p.m. Atlantic time two business days prior to the reconvened meeting date, to request a new Control Number for the meeting. This new Control Number will allow your proxyholder to log in to and vote at the meeting. Without a new Control Number your proxyholder will only be able to log in to the meeting as a guest and will not be able to vote. |
2. | This proxy confers discretionary authority on the appointee to vote as the appointee sees fit in respect of amendments or variations to matters identified in the notice of meeting or other matters as may properly come before the Meeting or any adjournment or postponement thereof, in each instance to the extent permitted by law, whether or not the amendment or other matter that comes before the meeting is routine and whether or not the amendment or other matter that comes before the meeting is contested. |
3. | This proxy must be signed by a holder or his or her attorney duly authorized in writing. If you are an individual, please sign exactly as your name appears on this proxy. If the holder is a corporation, a duly authorized officer or attorney of the corporation must sign this proxy. |
4. | If the securities are registered in the name of an executor, administrator or trustee, please sign exactly as your name appears on this proxy. If the securities are registered in the name of a deceased or other holder, the proxy must be signed by the legal representative with his or her name printed below his or her signature, and evidence of authority to sign on behalf of the deceased or other holder must be attached to this proxy. |
5. | Some holders may own securities as both a registered and a beneficial holder and will need to vote separately as a registered holder and as a beneficial holder. Beneficial holders may be forwarded either a form of proxy already signed by the intermediary or a voting instruction form to allow them to direct the voting of securities they beneficially own. Beneficial holders should follow instructions for voting conveyed to them by their intermediaries. |
6. | If a security is held by two or more individuals, any one of them present or represented by proxy at the Meeting may, in the absence of the other or others, vote at the Meeting. However, if one or more of them are present or represented by proxy, they must vote together the number of securities indicated on the proxy. |
7. | If this proxy is not dated, it will be deemed to bear the date on which it was mailed on behalf of management of the Company to you. |
All holders should refer to the Management Information Circular for further information regarding completion and use of this proxy and other information pertaining to the Meeting.
This proxy is solicited by and on behalf of Management of the Company.
Emera offers a number of ways to cast your vote prior to the meeting. By using one of these ways provided for you, you will be considered to have signed and returned this proxy.
Go to www.meeting-vote.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 |
Use any touch-tone telephone, call toll free in Canada and United States 1-888-489-5760 (English only) or 1-888-489-7352 (Bilingual) Follow the voice instructions When prompted, enter the 13-digit control number located on the reverse No need to return this proxy |
To vote using your smartphone, please scan this QR Code. No need to return this proxy.
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Complete the reverse of this form Return your signed proxy in the envelope provided or send to: TSX Trust Company P.O. Box 721 Agincourt, ON M1S 0A1 |
Complete the reverse of this form and fax your signed proxy to 416-595-9593. |
Complete the reverse of this form Scan your signed proxy and email it to proxyvote@tmx.com. |
All proxies must be received by 5:00 p.m. Atlantic time, Tuesday, May 21, 2024 or if the meeting is adjourned or postponed, by 5:00 p.m. Atlantic time two business days prior to the reconvened meeting date.
Exhibit 99.4
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Voting Instruction Form (VIF) - Emera Incorporated
Annual Shareholders Meeting of May 23, 2024
Appointee
I/We, being holder(s) of Emera Incorporated (the Company) common shares, hereby appoint: M. Jacqueline Sheppard, or failing her, Scott C. Balfour, or failing him, Brian C. Curry, OR
[To participate in the meeting and vote or to appoint someone to participate and vote on your behalf, print the name of the attendee here.]
as proxy of the undersigned, to participate, act and vote on behalf of the undersigned in accordance with the below direction (or if no directions have been given, as the proxy sees fit) on all of the following matters and any other matter that may properly come before the Annual Meeting of Shareholders of the Company to be held at 2:00 p.m. Atlantic time on Thursday, May 23, 2024, virtually via webcast at: https://web.lumiagm.com/407390256, using password: emera2024 (case sensitive) (the Meeting), and at any and all adjournments or postponements thereof in the same manner, to the same extent and with the same powers as if the undersigned were personally present, with full power of substitution.
Management recommends voting FOR Resolutions 1, 2, 3 and 4. Please use a dark black pencil or pen.
1. | Election of Directors | FOR | WITHHOLD | FOR | WITHHOLD | |||||||
01. Scott C. Balfour |
☐ | ☐ | 07. Brian J. Porter |
☐ | ☐ | |||||||
02. James V. Bertram |
☐ | ☐ | 08. Ian E. Robertson |
☐ | ☐ | |||||||
03. Henry E. Demone |
☐ | ☐ | 09. M. Jacqueline Sheppard |
☐ | ☐ | |||||||
04. Paula Y. Gold-Williams |
☐ | ☐ | 10. Karen H. Sheriff |
☐ | ☐ | |||||||
05. Kent M. Harvey |
☐ | ☐ | 11. Jochen E. Tilk |
☐ | ☐ | |||||||
06. B. Lynn Loewen |
☐ | ☐ | ||||||||||
2. | Appointment of Auditors | FOR | WITHHOLD | |||||||||
Appointment of Ernst & Young LLP as auditors | ☐ | ☐ | ||||||||||
3. | Authorized Remuneration of Auditors | FOR | AGAINST | |||||||||
Authorize Directors to fix the remuneration of the Auditors 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 Emeras 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 Managements 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.
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Signature(s) | Date |
Please sign exactly as your name(s) appears on this VIF. Please see reverse for instructions. All VIFs must be received by 5:00 p.m. Atlantic time, Tuesday, May 21, 2024 or if the meeting is adjourned or postponed, by 5:00 p.m. Atlantic time two business days prior to the reconvened meeting date.
Under Canadian Securities Law, you are entitled to receive certain investor documents. Electronic financial statements and MD&A are available at www.emera.com and at www.sedarplus.com. If you wish copies, please tick the box below or go to the website https://services.tsxtrust.com/financialstatements and input code 1705a.
❑ | I would like to receive interim financial statements and MD&A |
❑ | I would like to receive annual financial statements and MD&A |
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Voting Instruction Form (VIF) - Emera Incorporated
Annual Shareholders Meeting of May 23, 2024
1. | We are sending to you the enclosed proxy-related materials that relate to a meeting of holders of Emera Incorporateds common shares. Unless you, as an appointee, or an alternate appointee participate(s) in the Meeting and vote(s) in person or virtually, your securities can be voted only by management, as appointee of the registered holder, in accordance with your instructions. |
2. | Every shareholder has the right to appoint some other person or company of the shareholders choice, who need not be a shareholder of Emera Incorporated, to participate and act on the shareholders behalf at the meeting or any adjournment or postponement thereof. If you wish to appoint a person or company other than the persons whose names are printed herein, please insert the name of your chosen proxyholder in the space provided on the reverse and return your proxy by mail, fax or email. In addition, to enable your chosen proxyholder to participate and vote virtually at the Meeting YOU MUST contact TSX Trust Company TSX either by calling 1-866-751-6315 (toll-free within North America) or 1-416-682-3860 (outside North America) or logging onto the TSX website at: https://www.tsxtrust.com/control-number-request, by 5:00 p.m. Atlantic time on May 21, 2024 or if the meeting is adjourned or postponed, by 5:00 p.m. Atlantic time two business days prior to the reconvened meeting date, to request a new Control Number for the meeting. This new Control Number will allow your proxyholder to log in to and vote at the meeting. Without a new Control Number your proxyholder will only be able to log in to the meeting as a guest and will not be able to vote. Unless prohibited by law, the person whose name is written in the space provided will have full authority to present matters to the Meeting and vote on all matters that are presented at the Meeting, even if those matters are not set out in this form or the Management Information Circular. Consult a legal advisor if you wish to modify the authority of that person in any way. If you require help, please contact the Registered Representative who services your account. |
3. | This VIF confers discretionary authority on the appointee to vote as the appointee sees fit in respect of amendments or variations to matters identified in the notice of meeting or other matters as may properly come before the Meeting or any adjournment or postponement thereof, in each instance to the extent permitted by law, whether or not the amendment or other matter that comes before the meeting is routine and whether or not the amendment or other matter that comes before the meeting is contested. |
4. | We are prohibited from voting these securities on any of the matters to be acted upon at the Meeting without your specific voting instructions. In order for these securities to be voted at the Meeting, it will be necessary for us to have your specific voting instructions. Please complete and return the information requested in this VIF to provide your voting instructions to us promptly. |
5. | This VIF should be signed by you in the exact manner as your name appears on the VIF. If these voting instructions are given on behalf of a body corporate, set out the full legal name of the body corporate, the name and position of the person giving voting instructions on behalf of the body corporate, and the address for service of the body corporate. |
6. | If this VIF is not dated it will be deemed to bear the date on which it is mailed by management to you. |
7. | When properly signed and delivered, securities represented by this VIF will be voted as directed by you, however, if such a direction is not made in respect of any matter, the VIF will direct the voting of the securities to be made as recommended in the documentation provided by Management for the Meeting. |
8. | Your voting instructions will be recorded on receipt of the VIF. |
9. | By providing voting instructions as requested, you are acknowledging that you are the beneficial owner of, and are entitled to instruct us with respect to the voting of, these securities. |
10. | If you have any questions regarding the enclosed documents, please contact the Registered Representative who services your account. |
11. | This VIF should be read in conjunction with the Management Information Circular and other proxy materials provided by Management. |
All holders should refer to the Management Information Circular for further information regarding completion and use of this VIF and other information pertaining to the Meeting.
Emera offers a number of ways to cast your vote prior to the meeting.
Go to www.meeting-vote.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 |
Use any touch-tone telephone, call toll free in Canada and United States
1-888-489-5760 (English only) or 1-888-489-7352 (Bilingual)
Follow the voice instructions
When prompted, enter the 13-digit control number located on the reverse
No need to return this VIF |
To vote using your smartphone, please scan this QR Code. There is no need to return this VIF.
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Complete the reverse of this form
Return your signed VIF in the envelope provided or send to:
TSX Trust Company P.O. Box 721 Agincourt, ON M1S 0A1 |
Complete the reverse of this form Fax your signed VIF to 416-595-9593 |
Complete the reverse of this form
Scan your signed VIF and email it to proxyvote@tmx.com. |
All VIFs must be received by 5:00 p.m. Atlantic time, Tuesday, May 21, 2024 or if the meeting is adjourned or postponed,
by 5:00 p.m. Atlantic time two business days prior to the reconvened meeting date.
Exhibit 99.5
ANNUAL SHAREHOLDERS MEETING OF
EMERA INCORPORATED
NOTICE TO REGISTERED SHAREHOLDERS
REGARDING ACCESS TO EMERAS MANAGEMENT INFORMATION CIRCULAR
and ANNUAL REPORT
MEETING DATE and LOCATION | ||
Date: | Thursday, May 23, 2024 | |
Time: | 2:00 p.m. Atlantic time | |
Place: | Virtual-only meeting via live webcast online at: https://web.lumiagm.com/407390256 Meeting password: emera2024 (case sensitive) |
Q | WHY AM I RECEIVING THIS NOTICE? |
A | As permitted by Canadian securities regulators, Emera Incorporated (Company) is providing you with access to our management information circular (Information Circular) for the annual shareholders meeting (Meeting) as well as the 2023 Annual Report (together, the Meeting Materials), electronically, instead of mailing paper copies. This notice provides you with information on how to view the Meeting Materials online and / or request paper copies. Accompanying this notice is the proxy form that you will need to vote. |
Q | WHERE CAN I ACCESS THE MEETING MATERIALS ON-LINE? |
A | The Meeting Materials can be viewed online at www.meetingdocuments.com/TSXT/ema as of Monday, April 8, 2024 for a period of one year following the Meeting, or at www.sedarplus.com. |
Q | HOW CAN I OBTAIN A PAPER COPY OF THE MEETING MATERIALS? |
A | At any time prior to the date of the Meeting, you can request a paper copy of the Meeting Materials free of charge by calling the phone number, sending an email or accessing the website below: |
| Phone number: Toll free 1-888-433-6443 (or 1-416-682-3801 for shareholders outside of Canada and the United States) |
| Email address: tsxt-fulfilment@tmx.com |
| Website: www.meetingdocuments.com/TSXT/ema |
Paper copies requested before the date of the Meeting will be sent to you within three business days of receiving your request. Therefore, to receive the Meeting Materials prior to the proxy deadline for the Meeting described below, you should make your request before 11:00 a.m. Atlantic time on Wednesday, May 8, 2024. To receive the Meeting Materials prior to the Meeting you should make your request before 11:00 a.m. Atlantic time on Friday, May 10, 2024.
Paper copies of the Meeting Materials requested on or after the date of the Meeting will be sent to you within 10 calendar days after receiving the request. Requests for paper copies of the Meeting Materials can be made until one year following the Meeting.
Q | WHAT MATTERS ARE BEING RECEIVED OR VOTED ON AT THE MEETING? |
A | Shareholders are being asked to vote on the following items of business: |
MEETING BUSINESS ITEM |
INFORMATION CIRCULAR REFERENCE | |
1. Election of the Board of Directors elect Directors of the Company for the ensuing year. |
See the section entitled Business of the Meeting -Election of the Board of Directors in the Information Circular for more information. | |
2. Appointment of Auditors appoint Ernst & Young LLP as auditors for the ensuing year. |
See the section entitled Business of the Meeting -Appointment of Auditors in the Information Circular for more information. | |
3. Authorize Remuneration of Auditors authorize the Directors to fix the remuneration of the Auditors. |
See the section entitled Business of the Meeting -Auditors Fee in the Information Circular for more information. | |
4. Advisory Vote on Executive Compensation - Consider and approve, on an advisory basis, a resolution on Emeras approach to executive compensation. |
See the section entitled Business of the Meeting -Advisory Vote on Executive Compensation (say on pay) in the Information Circular for more information. |
All Shareholders are reminded to review the Information Circular before voting. |
Q | HOW DO I VOTE MY SHARES? |
A | You may vote by Internet, telephone, posted mail, delivered mail, e-mail, fax or via live webcast. Details of the methods of voting can be found on your accompanying proxy form. You will need your control number contained in the proxy form in order to vote by telephone, by Internet or via the live webcast. |
To be valid, proxy forms or voting instructions must be received by Emeras Corporate Secretary, c/o TSX Trust Company at P.O. Box 721, Agincourt, ON M1S 0A1 by no later than 5:00 p.m. Atlantic time on Tuesday, May 21, 2024 or, if the Meeting is adjourned or postponed, by 5:00 p.m. Atlantic time two business days before the reconvened meeting date. Emera reserves the right to accept late proxies or voting instructions and to waive the proxy deadline, with or without notice, but is under no obligation to accept or reject any particular late proxy or voting instructions.
If you wish to appoint someone else to participate and vote virtually on your behalf, you MUST appoint your chosen proxyholder using your proxy form. IN ADDITION, in order for your chosen proxyholder to participate and vote virtually at the Meeting, you must contact TSX Trust by 5:00 p.m. Atlantic time on Tuesday, May 21, 2024 to request a new Control Number for the Meeting. In order to request a new Control Number, please visit TSX Trusts website at: https://www.tsxtrust.com/control-number-request and complete an electronic form. This form once completed and submitted online will generate a message to TSX Trust to send the new Control Number to the designated proxyholder. This new Control Number will allow your chosen proxyholder to log in to and vote at the Meeting. Without a new Control Number your proxyholder will only be able to log in to the Meeting as a guest and will not be able to vote.
Q | WHO CAN I CONTACT IF I HAVE QUESTIONS ABOUT NOTICE & ACCESS? |
A | Shareholders with questions about notice and access can call toll free at 1-888-433-6443 or shareholders outside of Canada and the United States can call 1-416-682-3801, or email tsxt-fulfilment@tmx.com. |
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Exhibit 99.6
ANNUAL SHAREHOLDERS MEETING OF
EMERA INCORPORATED
NOTICE TO NON-REGISTERED SHAREHOLDERS
REGARDING ACCESS TO EMERAS MANAGEMENT INFORMATION CIRCULAR
and ANNUAL REPORT
MEETING DATE and LOCATION | ||
Date: | Thursday, May 23, 2024 | |
Time: | 2:00 p.m. Atlantic Time | |
Place: | Virtual-only meeting via live webcast online at: https://web.lumiagm.com/407390256 Meeting password: emera2024 (case sensitive) |
Q | WHY AM I RECEIVING THIS NOTICE? |
A | As permitted by Canadian securities regulators, Emera Incorporated (Company) is providing you with access to our management information circular (Information Circular) for the annual shareholders meeting (Meeting) as well as the 2023 Annual Report (together, the Meeting Materials), electronically, instead of mailing paper copies. This notice provides you with information on how to view the Meeting Materials online and / or request paper copies. Accompanying this notice is the voting instruction form that you will need to vote. |
Q | WHERE CAN I ACCESS THE MEETING MATERIALS ON-LINE? |
A | The Meeting Materials can be viewed online www.meetingdocuments.com/TSXT/ema as of Monday, April 8, 2024 for a period of one year following the Meeting, or at www.sedarplus.com. |
Q | HOW CAN I OBTAIN A PAPER COPY OF THE MEETING MATERIALS? |
A | At any time prior to the date of the Meeting, you can request a paper copy of the Meeting Materials free of charge by calling the phone number, sending an email or accessing the website below: |
| Phone number: Toll free 1-888-433-6443 (or 1-416-682-3801 for shareholders outside of Canada and the United States) |
| Email address: tsxt-fulfilment@tmx.com |
| Website: www.meetingdocuments.com/TSXT/ema |
Paper copies requested before the date of the Meeting will be sent to you within three business days of receiving your request. Therefore, to receive the Meeting Materials prior to the proxy deadline for the Meeting described below, you should make your request before 11:00 a.m. Atlantic time on Wednesday, May 8, 2024. To receive the Meeting Materials prior to the Meeting you should make your request before 11:00 a.m. Atlantic time on Friday, May 10, 2024.
Paper copies of the Meeting Materials requested on or after the date of the Meeting will be sent to you within 10 calendar days after receiving the request. Requests for paper copies of the Meeting Materials can be made until one year following the Meeting.
Q | WHAT MATTERS ARE BEING RECEIVED OR VOTED ON AT THE MEETING? |
A | Shareholders are being asked to vote on the following items of business: |
MEETING BUSINESS ITEM |
INFORMATION CIRCULAR REFERENCE | |
1. Election of the Board of Directors elect Directors of the Company for the ensuing year. |
See the section entitled Business of the Meeting - Election of the Board of Directors in the Information Circular for more information. | |
2. Appointment of Auditors appoint Ernst & Young LLP as auditors for the ensuing year. |
See the section entitled Business of the Meeting -Appointment of Auditors in the Information Circular for more information. | |
3. Authorize Remuneration of Auditors authorize the Directors to fix the remuneration of the Auditors. |
See the section entitled Business of the Meeting -Auditors Fee in the Information Circular for more information. | |
4. Advisory Vote on Executive Compensation - Consider and approve, on an advisory basis, a resolution on Emeras approach to executive compensation. |
See the section entitled Business of the Meeting Advisory Vote on Executive Compensation in the Information Circular for more information. |
All Shareholders are reminded to review the Information Circular before voting. |
Q | HOW DO I VOTE MY SHARES? |
A | Details of the methods of voting can be found on your accompanying voting instruction form (VIF). To the extent specified on your VIF, you may vote by Internet, telephone, posted mail, delivered mail, e-mail, fax or via live webcast. You will need your control number contained in the VIF in order to vote by telephone, by Internet or via the live webcast. |
To be valid, voting instructions must be received by Emeras Corporate Secretary, c/o TSX Trust Company at P.O. Box 721, Agincourt, ON M1S 0A1 by no later than 5:00 p.m. Atlantic time on Tuesday, May 21, 2024 or, if the Meeting is adjourned or postponed, by 5:00 p.m. Atlantic time two business days before the reconvened meeting date. However, it is important to note that your voting instructions must be submitted to your broker or other intermediary by the deadline specified in the VIF and, in any case, at least one business day in advance of the proxy deadline to provide sufficient time for your broker or other intermediary to act on those instructions prior to the 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 instructions.
To participate and vote at the Meeting virtually, or if you wish to appoint someone else to participate and vote virtually on your behalf, you MUST appoint yourself or your chosen proxyholder using your VIF. IN ADDITION, in order for your chosen proxyholder to participate and vote virtually at the Meeting, you must contact TSX Trust by 5:00 p.m. Atlantic time on Tuesday, May 21, 2024 to request a new Control Number for the Meeting. In order to request a new Control Number, please visit TSX Trusts website at: https://www.tsxtrust.com/control-number-request and complete an electronic form. This form once completed and submitted online will generate a message to TSX Trust to send the new Control Number to the designated proxyholder. This new Control Number will allow you or your chosen proxyholder to log in to and vote at the Meeting. Without a new Control Number you or your proxyholder will only be able to log in to the Meeting as a guest and will not be able to vote.
Q | WHO CAN I CONTACT IF I HAVE QUESTIONS ABOUT NOTICE & ACCESS? |
A | Shareholders with questions about notice and access can call toll free at 1-888-433-6443 or shareholders outside of Canada and the United States can call 1-416-682-3801, or email tsxt-fulfilment@tmx.com. |
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