Good morning, ladies and gentlemen, welcome to Emera's Q1 2019 analyst conference call. After the presentation, we will conduct a question and answer session. Instructions will be provided at that time. Please note that this call is being recorded today, Friday, May 10th, 2019, at 8:30 A.M. Eastern Time. I would now like to turn the meeting over to your host for today's call, Erin Power, Manager Investor Relations for Emera. Please go ahead, Ms. Power.
Thank you, Melissa, thank you all for joining us this morning for Emera's first quarter 2019 conference call and live webcast. Emera's first quarter earnings release was distributed this morning via Newswire, and the financial statements, management's discussion and analysis, and the presentation being referenced on this call are available on our website at emera.com. Joining me for this morning's call are Scott Balfour, Emera's President and Chief Executive Officer, Greg Blunden, Emera's Chief Financial Officer, and other members of Emera's management team. Before we begin, I will take a moment to advise you that this morning's discussion will include forward-looking information, which is subject to the cautionary statement contained in the supporting slideshow. Today's discussion and presentation will also include references to non-GAAP financial measures. You should refer to the supporting slides for definitional information and reconciliations of historical non-GAAP measures to the closest GAAP financial measure.
Now, I will turn things over to Scott.
Thanks, Erin, good morning, everyone. Our businesses continued to perform very well during the first quarter. As a result, this morning, Emera reported adjusted first quarter earnings per share of CAD 0.95, an increase of 9% over the first quarter of 2018. Growth in the quarter was largely driven by strong results at Nova Scotia Power and our gas utilities. I'm also pleased with the operating cash flow being generated by our business. Although cash flow was down modestly compared to the first quarter of 2018, I expect this trend to reverse over the course of the year.
All to say, we're off to a strong start, and the results of the first quarter give us increased confidence that we will deliver adjusted EPS for the year that is consistent with 2018 levels when normalized for one-time impacts in both years, notwithstanding the sale of our gas plants and the resulting loss of those earning contributions for the balance of the year relative to 2018. Our financial success is a direct result of how we've been consistently executing on our proven strategies. By continuing to focus on delivering cleaner, affordable, reliable energy to our customers, we've been able to create unique and innovative opportunities to invest that have provided value to customers and shareholders alike. Ensuring that energy is affordable for our customers is always a focus when we're looking to invest.
One way we've been able to successfully manage customer rates while growing rate base is by looking for opportunities to convert flow-through costs like fuel and O&M into rate-based investment opportunities. Our investments in expanding solar generation, modernizing Big Bend, and deploying smart meters are great examples of this strategy in action. Today, Tampa Electric has over 445 megawatts of solar capacity, in 2019, solar energy will account for approximately 5% of Tampa Electric's total generation. By 2021, those numbers will grow to be over 640 megawatts of capacity, which means approximately 7% of Tampa Electric's generation will come from the sun. That's a significant increase, especially when you consider that just two years ago, those numbers were effectively zero.
Expanding our use of solar generation is the right thing to do for our customers and the environment, we've been able to make these rate-based investments in a way that is affordable for customers by removing fuel costs. Our use of a solar-based rate adjustment ensures that our investment in solar is reflected in rates once the capacity is in service. Today, approximately 405 megawatts of our solar capacity is being paid through this mechanism, which is expected to generate approximately $70 million of revenue and $30 million of net earnings in 2019. We also continue to make progress on the Big Bend modernization and anticipate breaking ground at this site this summer. Once complete, this $850 million investment will reduce GHG emissions from the facility by about 30% and will save customers $750 million over the life of the investment.
In addition, a modernized Big Bend will help to improve system reliability and support future investment in even more renewables. Our cross-utility smart meter program is in full swing. Smart meter installations have begun at Tampa Electric, with approximately 170,000 meters now installed, Nova Scotia Power expects to begin installing the first meters in its customers' homes this fall. Once the meters and supporting infrastructure are installed, our customers will enjoy greater access to their energy data, our utilities will be able to manage their systems more effectively. As we've been executing on our strategy, we've also been working to ensure that we are ready to meet the changing needs of our customers. We've launched a number of small, customer-focused projects throughout our utilities to increase options for our customers to access clean, reliable energy in new ways.
This will allow us to learn about new technologies, including smart grids and battery storage. At Tampa Electric, the team is working through the final stages of regulatory approval to launch Sun Select, a new 17.5-megawatt community solar program for their residential and small commercial customers. Pending approval from the Florida Public Service Commission, Sun Select will enable our customers to purchase solar energy from our newly commissioned Lake Hancock site. With approximately 75% of Tampa Electric customers unable to install rooftop solar, this program will provide a cost-competitive alternative to customers who want to use solar. Given our customers' increasing interest in solar energy, we are optimistic that this program will be successful, and we will continue to look for opportunities to further expand Sun Select. We're very optimistic about the continued expansion of solar generation in Florida. The intermittent nature of renewable energy does create challenges for the grid, however.
The team in Tampa is excited to be investing in a 13-megawatt, 26-megawatt hour battery energy storage system that will be co-located at the existing Big Bend solar site. By leveraging the existing Big Bend infrastructure, we are able to be efficient with the capital investment in the project. Integrating grid-scale battery storage into Tampa Electric's system will allow the team to learn even more about managing intermittent generation and prepare them to deploy further battery storage as the technology becomes more cost-effective. The team is well advanced on the project, and it's expected to be operational this fall. The team at Nova Scotia Power has partnered with Siemens and New Brunswick Power to develop a smart grid platform that will be piloted in each of the two provinces.
NSP is working with the town of Amherst to develop an energy control platform, build a two-megawatt community solar farm, and install four on-site solar generation and battery storage systems at commercial businesses within the town. It's an exciting project that will help Nova Scotia Power learn how to best incorporate these technologies to better serve customers while adding enough renewable energy to the grid to serve over 200 customers. The project has received CAD 13 million in federal funds. Nova Scotia Power will seek regulatory support for the balance by demonstrating value creation for its customers to engage in this innovative work. We're committed to our CAD 6.5 billion capital program over the next three years, and we are on track to invest CAD 2.5 billion in 2019.
Over the next three years, approximately 75% of that capital will be deployed in our electric utilities, where investments in solar generation, modernizing Big Bend, and smart meters form the foundation of the capital program. The remaining 25% will be invested in our gas utilities, where the focus is on system expansion to support customer growth and enhance reliability and opportunities to attract new types of commercial customers. The vast majority of our investments are focused in Florida and Atlantic Canada, which together account for over 85% of our planned capital spend. With the majority of our capital being deployed in the state of Florida, a jurisdiction with healthy equity thickness in ROEs, we expect to achieve higher EPS growth and continue to improve our balance sheet to our target capital structure over the period.
All to say, our capital investment program is expected to continue to drive healthy rate base growth of 6% through 2021, notably driven by very strong rate base growth in our Florida utilities. As we've noted in the past, the rate base profile only includes projects that we are highly confident will proceed. Additional capital investment opportunities, including further investments in solar in Florida, will sustain or enhance our long-term rate base growth. As I look out beyond 2021, I'm confident that we will continue to deliver a competitive rate base growth profile for our shareholders, given the high quality of our businesses and the proven and sustainable nature of our strategy. Executing on this strategy for over a decade has enabled us to grow into a top 20 North American utility while delivering above-average total returns to our shareholders.
Along the way, we've successfully transformed the energy landscape here in Nova Scotia, and we're well on our way to a similar transformation in Florida. I believe that the themes of cleaner generation, customer-focused technologies, and infrastructure renewal that we are investing in today will continue to provide investment opportunities for Emera for years to come. So far in 2019, we've continued to make significant progress against our funding plan. One of the key objectives of our plan is to significantly reduce and potentially eliminate the need for any discrete external common equity offerings. I'm pleased to say that upon closing of the announced sale of Emera Maine, we will have successfully achieved that objective. Upon closing, total proceeds from select asset sales will be approximately CAD 2.1 billion, which fully meets our asset sale target.
Our equity needs in support of our CAD 6.5 billion capital plan is now limited to funds raised in small increments through our DRIP, the hybrid capital markets, and the possible introduction of an at-the-market or ATM program. Together, these tools give us the flexibility to optimize how we raise our equity capital to maximize value for shareholders. As part of this morning's earnings release, we announced that we have revised the discount being offered to shareholders choosing to participate in our dividend reinvestment plan from 5% to 2%. This change brings our discount in line with industry peers while still providing value to those elect to participate in the DRIP. We're off to a strong start in 2019, and I'm pleased with the progress we've made so far this year. The business has continued to deliver strong financial results for our shareholders while making measurable progress on our strategic initiatives.
We've continued to execute on our asset sale program, which is on track to be completed by the end of 2019. I'm also pleased with the progress we've made on strengthening our balance sheet. As Greg will walk you through in a moment, the actions of management have firmly positioned Emera to focus on continuing to deliver growth and superior returns for our shareholders. With that, I'll turn it over to Greg to take you through our financial results.
Thank you, Scott, and thank you all for joining us this morning. As Scott highlighted, we are off to a strong start in 2019. Our operating assets have performed exceptionally well, delivering continued EPS growth to our shareholders. For the first quarter of 2019, Emera reported adjusted net income, which excludes mark-to-market adjustments, of CAD 224 million, or CAD 0.95 per share, compared with adjusted net income of CAD 202 million and CAD 0.87 per share in the first quarter of 2018. This represents a 9% increase in adjusted EPS. Growth in the quarter was driven by strong results at Nova Scotia Power and our gas utilities. For the quarter, the business delivered operating cash flow before changes to net working capital of CAD 418 million, compared to CAD 444 million in the first quarter of 2018.
This modest decrease is primarily related to costs associated with asset sales, including taxes and advisor fees, whereas the gross proceeds are included in our investing cash flows. I expect that this decrease will reverse over the balance of the year, and our business will deliver annual cash flow which is consistent with 2018. Operating cash flow is an important metric for our business and is the basis upon which our credit metrics are calculated. As I'll take you through in a few moments, our improved cash flow, combined with the results of our funding initiatives, is expected to drive continued improvement in our cash flow debt metrics in both 2019 and 2020. Growth in first quarter EPS was primarily driven by strong results in our gas utilities and at Nova Scotia Power.
In the quarter, New Mexico Gas Company contributed $23 million US dollars to net earnings, an increase of $7 million or 35% compared to the first quarter of 2018. These strong results were driven by favorable weather conditions, which provided the utility the opportunity to earn an incremental $6 million US dollar margin compared to the first quarter of last year. Through the ongoing optimization of its pipeline capacity, which added a further $2 million US dollars of earnings in the quarter. Activity in the Permian Basin is creating opportunities for New Mexico Gas to take advantage of its excess transmission pipeline capacity. In 2018, the utility entered into an asset management agreement, or AMA, that allows the counterparty to optimize the use of New Mexico's excess capacity.
The AMA is benefiting both customers and shareholders. Both parties to the agreement are very happy with its performance to date. Earnings contribution from the agreement are seasonal and will be the highest in the first and fourth quarters of the year. At Peoples Gas, customer growth of 3.1% and lower depreciation and amortization costs offset the effects of less favorable weather conditions in the quarter. The change in amortization cost was driven by the timing of regulatory amortization associated with former manufactured gas plant sites, or MGP. As part of the 2017 settlement agreement, CAD 11 million of MGP-related amortization was to be recorded over the 2018 to 2020 periods. In 2018, PGS accelerated the recognition of the remaining MGP-related amortization, including recording CAD 3.5 million in the first quarter of 2018. As a result of this acceleration, there are no MGP-related amortization costs in 2019.
In Nova Scotia, favorable weather conditions and less storm activity increased Nova Scotia Power's earnings contribution in the quarter. While I'm pleased with the results the utility has delivered in the quarter, it's important to remember that Nova Scotia Power's annual earnings growth is largely driven by its rate base growth, while the timing of the earnings contribution will be dependent on market conditions, including weather. All to say, we continue to expect the full-year results for Nova Scotia Power will reflect more modest growth. Although the earnings contribution from other was flat to Q1 of 2018, I'd like to spend a few minutes to walk through some of the individual pieces.
At Emera Energy, marketing and trading margin decreased by CAD 15 million as a result of less favorable market conditions relative to Q1 2018, when the impact of colder weather resulted in higher market prices and volatility that then led to higher margins. Although margin has decreased relative to Q1 2018, marketing and trading is still off to a strong start for the year, and I expect that they will earn within their $15 million-$30 million US dollar earnings guidance range for the year. In corporate, higher financing costs and a CAD 2 million loss on the sale of Bayside and New England Gas Generation facilities were partially offset by a CAD 10 million gain on the sale of some property in Florida. As Scott highlighted in his remarks, we continue to make progress against our three-year funding plan that we first outlined last fall.
Notably, upon closing the announced sale of Emera Maine, we will have raised CAD 2.1 billion of proceeds and met the asset sale target in our funding plan. By engaging in select asset sales, we will have successfully eliminated the need for a discrete equity offering to fund our CAD 6.5 billion baseline capital program and accelerate the transition of our balance sheet back to our targeted capital structure. The Emera Maine sale is progressing as expected, and we are working closely with ENMAX through the regulatory process. The team has begun to make filings with the various regulatory bodies required to approve the transaction, including FERC and the Maine Public Utilities Commission, and we anticipate the transaction will close later this year. Turning to our funding plan, we continue to see the DRIP and preferred shares as helpful components to financing our growth.
However, as capital markets change, we would be prudent to add another flexible, proactive mechanism to our toolbox. In that regard, we have been assessing the potential for establishing an at-the-market or ATM program to round out our equity needs over the remainder of the three-year forecast period. A necessary first step in this process is the filing of a preliminary shelf prospectus, which was completed yesterday. Once final, and provided we have all the necessary exemptive relief in hand, the shelf will allow common share offerings of up to CAD 600 million in aggregate over a period of 25 months. An ATM program will allow us to raise modest levels of equity in a cost-effective and less dilutive manner on a just-in-time basis, providing us with increased funding flexibility and allowing us to match equity raises with normal course business requirements such as growth.
Our funding plan is designed to increase Emera's financial strength by delivering on four key objectives. With the sale of the NEGT portfolio and the Bayside plant, we have met our first objective of improving our business risk. Removing these assets from our portfolio has significantly reduced our exposure to merchant generation, strengthening our overall business risk profile. Our second objective is to increase our sustained cash flow debt metrics. We have been steadily improving these metrics since the TECO acquisition in 2016. Over the course of 2019, we would expect our cash flow debt metrics to gradually improve towards our 12% target as we maintain consistent levels of cash flow and use proceeds through asset sales to repay holding company debt.
We continue to execute on our funding plan throughout 2019 and look forward to 2020, we would expect these metrics to continue to strengthen to 12% by the end of next year, with the objective of sustaining this level or higher over the longer term. Third, we are focused on materially reducing our holding company debt as a percentage of our total debt. After the acquisition of TECO in 2016, our holding company leverage was over 50%. Today, approximately 44% of our debt is at the whole co level, and we would expect that to be below 40% with the closing of the sale of Emera Maine. Finally, our funding plan is designed to decrease our consolidated leverage and accelerate our transition back to our targeted capital structure. Achieving our targeted capital structure will enable us to meet our target credit metrics.
Successfully executing our asset sale program has accelerated the transition. We anticipate upon closing of the Emera Maine transaction, we will achieve our targeted capital structure of 55% debt, 35% equity and 10% hybrid capital. Overall, I'm pleased with our strong start to 2019. While 2019 will be a transition EPS year for Emera, solid first quarter results give me the confidence that we will deliver adjusted EPS that's consistent with 2018 when adjusting for the one-time tax benefits last year. Our portfolio of regulated assets continues to perform exceptionally well, and we believe that our prudent and disciplined allocation of capital in 2019 will result in a stronger Emera that is well-positioned to continue to deliver long-term earnings and cash flow growth for our shareholders. With that, I'll turn the presentation back over to Erin.
Thank you, Greg. This concludes the presentation. We would now like to open up the call to take questions from analysts.
Thank you. If you would like to ask a question at this time, simply press star, then the number one on your telephone keypad. To withdraw your question, press the pound key. Your first question comes from the line of Robert Hope from Scotiabank. Your line is open.
Good morning, everyone. Congrats on a good quarter. I want to start off down in Florida. Just want to get a sense of what quantum of opportunities you're thinking you can get out of battery storage as well as some of these community storage opportunities longer term. Is it really the focus more on the larger scale solar?
Thanks, Rob. I know Nancy's on. Nancy, you want to take that question?
I can start, Scott. I'll say a few things you may want to finish. On the community solar, we're starting with 17.5 megawatts. We'll see where that goes. I think we still believe that there is more utility scale solar. We're pursuing land acquisition and continuing to assess the building of the next 300 or 600 megawatts of solar. We still believe that's an opportunity. I think the battery storage will help us understand integration of batteries into solar and help us make that solar generation more efficient than it is today.
Rob, I think it's fair to say, obviously, we've started with a robust program at the large scale with the first 600 megawatts and planning to continue to build on that. As it relates to community solar and storage, it's still early days. We're excited about where it can go. We've got some meaningful projects that are underway now, but we haven't fully framed up what the opportunity is, and that opportunity set will continue to clarify itself and frankly grow as the technology and the cost competitiveness of it continues to improve.
All right. As a follow-up, Lakeland's looking to shut down a coal unit. Is this an opportunity for you to potentially add some generation in your territory to serve that territory, which would be quite close?
Rob, we haven't specifically looked at that. We obviously know Lakeland fairly well, and we've got a good relationship with them, but we haven't specifically looked at that opportunity.
All right. Thank you.
Thanks, Rob.
Your next question comes to the line of Robert Kwan from RBC Capital Markets. Your line is open.
Good morning. Just looking at the funding waterfall and the residual CAD 900 million number. I'm just wondering, how are you thinking about that? Where's the priority? Is it balance sheet strengthening, and therefore DRIP and ATM being the full equity products would have the greatest impact? Or do you see it more minimizing dilution, i.e. minimizing share count?
Hi, Robert. It's Greg. I think the answer is both, and there's also a timing component in terms of when the capital gets spent. We've been fairly disciplined through all this. We want to raise our capital in the most cost-effective way that is most supportive of credit metrics, at the same time, not being dilutive to existing shareholders, and we'll continue to do that. I think, when you look at that waterfall and the CAD 900 million, that's over a three-year period. The timing of each and every one of those components will vary based on other factors.
Got it. I guess, just to clarify on the pace, it sounds like it's more about taking your time with it, since most of the heavy lifting is done, and pacing it with the capital plan versus just trying to get it out of the way up front?
That is correct.
Okay. If I can just ask one more question here. As you think about your long-term kind of funding and financial setup strategy, I'm just wondering what's on or off the table as you think about your payout and leverage, 70%-75% long-term target, and you've got your 4%-5% dividend growth. I guess, is there any contemplation of slowing the dividend growth or even going no growth to drive that payout ratio faster down to something in that 60% range like the U.S. peers?
I'd say that's not under contemplation at the current moment, Robert. Obviously, dividend increases are in the purview of the board. Obviously, when we established the 4%-5% dividend growth rate target, we did that with clarity and understanding as to the path that we were on, including the asset sales and our view as to the capital investment program that's in front of us and the earnings growth that can drive, and comfort that the dividend payout ratio will reduce itself over time while our cash flow metrics continue to be strong. We're comfortable with the path that we're on and frankly don't see a need to make any changes. All that said, of course, highlighting the fact that dividend increases are ultimately determined by the board on an annual basis.
Understood. Great. Thank you very much.
Sure.
Again, if you would like to ask a question, press star, then the number one on your telephone keypad. Your next question comes from the line of Ben Pham from BMO. Your line is open.
Okay, thanks. Good morning. Just with the resegmentation and looking at the Florida electric utilities, you saw earnings flat year-over-year. You provided some variances for that. Was it mostly the weather that was negatively impacting just some of the positive AFUDC currency tailwinds that you saw?
Yeah, Ben, it's Greg. It's virtually all weather. If you think of Q1 last year, Florida had unusually cold weather in the first 6 weeks or so, which is helpful to load, then it immediately got extremely hot. Then you'll recall that was kind of mitigated in the next couple of quarters, then kind of balanced out over the course of the year. We're probably seeing much more, I'd say, normalized weather in the first quarter of this year compared to what we saw last year. Of course, we're just getting into the second and third quarters, where typically load picks up materially at Tampa Electric.
Okay. Secondly, going back to some of the questions on the funding waterfall, you previously had the pref hybrid in a separate bucket. Now you're adding it together, calling it equity. Is the thinking now that really the pref side, it's not definitive now on whether you could access that market and it's really just looking at all of the above and seeing what's the best cost of capital?
Yeah. Ben, certainly, when you compare the equity markets and the bond markets to the pref markets, the pref markets really haven't come back in balance the way the other markets have. Certainly, we would be able to issue pref if we wanted to, albeit I'm less so sure we would necessarily like the pricing we'd see in this current market. Our thinking is, it's collectively that, whether it's a potential at-the-market program, whether it's our DRIP or whether it's the pref is as the funding requirement is there, we'll do what is the most cost-effective for the business overall at that particular point in time.
Okay, that's great. Thank you.
Your next question comes from the line of Nicholas Campanella from Bank of America Merrill Lynch. Your line is open.
Hey, good morning.
Hi, Nick.
I was just wondering, just to go back to the Florida opportunities, I think we all saw some recent legislation passed as it relates to undergrounding of the distribution network.
Sure.
Is there any way you can kind of talk about what's in your CapEx budget currently, or give us a sense of how much Tampa Electric's distribution network is above ground and whether this is an opportunity into your next CapEx update? Thanks.
Well, I can start, Nick. It's Greg, and then Nancy, you can add on. In our current capital forecast, it's still early days. The legislation that you referenced, it still has to go to the PUC for rulemaking, et cetera. It's too early to speculate on the timing and what that could effectively mean. As a result of that, our baseline CAD 6.5 billion CapEx program doesn't include anything that would be the result of that legislation.
Greg, I'll just add that today, about 40% of our distribution is underground.
There certainly is a desire in Florida as a result of the hurricanes to get more of that underground, obviously, and this legislation sort of proves that out. To Greg's point, we will put together a plan as required by the legislation, and be ready to file it once the rulemaking is done.
Thanks. Appreciate that. Greg, I just wanted to clarify your comments. Is it 12% FFO to debt you're targeting by the end of 2020 now?
Yeah. Over the end of this year and through 2020, we would expect to hit that over that sometime over that 12-month period.
Thank you.
Again, if you would like to ask a question, press star, then the number 1 on your telephone keypad. Your next question comes from the line of David Quezada from Raymond James, your line is open.
Thanks. Morning, guys. My first question, just on the sale of Emera Maine, it looks like you got a pretty attractive multiple there. I am wondering if you can provide any color on what the sale process was like there, degree of competition, et cetera.
Yeah. We did run a process. It was competitive. Ultimately, obviously, ENMAX was successful bidder through that process. It was highly competitive, and we're pleased with the result and working with focus towards the regulatory approval process that's in front of us that, as mentioned, we expect should be done by the end of the year.
Okay, great. Thanks for that. Maybe just a broader question. Just thinking about how much better the regulatory characteristics tend to be in the U.S., and obviously your capital program is weighted there. Wondering what kind of catalyst you'd need to deploy more capital in Canada. I guess, if the projects were there, is it a matter of opportunities or a matter of waiting for the regulators to maybe improve those characteristics in Canada?
Look, I think at the end of the day, it's about balance. As mentioned in my remarks, as we continue to invest in equity in order to bring in new technology, in order to clean generation, in order to renew existing or aging infrastructure, all that has to be done obviously, with support of regulators and other important stakeholders in the process. An important part of that is making sure that it remains affordable for customers. The businesses all across Emera, but certainly here in Nova Scotia, is working very hard in order to meet those needs of customers, and invest in those technologies, but to do it in a way that isn't putting undue pressure on rates.
We're proud of what we've been able to accomplish there over the last few years with no increases in base rates for quite a number of years now. Focusing on things like deploying smart meters and AMI, where it can not only provide benefit to customers but create some efficiencies within the business, helps to meet that affordability goal. These are all things that we do, and we've done this for a long period of time. The opportunity to continue to invest in the capital program that's in front of us that will continue to grow and roll out as we keep doing our three-year refresh, will always be done with that lens in mind.
Thank you for that. That's it for me. Thanks.
Thank you.
Your next question comes from the line of Patrick Kenny from National Bank Financial. Your line is open.
Yeah. Good morning, everyone. Just wanted to ask from an ESG perspective, in light of your recent divestitures and continued focus on Florida Solar and installing smart meters, where you guys might be at, roughly speaking, with respect to your GHG emission goals relative to a couple of years ago. Directionally, are you tracking above or below targets? Maybe you can touch on how these environmental targets outside of rate-based growth are influencing your capital allocation decisions over the next three years.
Patrick, Scott again. I think, we're really proud of what we've been able to accomplish on the ESG front and environmental carbon emissions, GHG emissions, among that. We've achieved now a 70% reduction in the amount of coal usage across the business. If you turn to Nova Scotia, where this journey began some time ago, we've already exceeded the COP 21 goals that were established as it relates to carbon reductions against the 2005 baseline and have a goal of further reductions that would actually see us doubling the, or near doubling the COP 21 goal by 2030. This is, I think, where Emera's strategy has been so beneficial as it relates to that goal of cleaner energy, with focus on reliability and affordability.
The investments that we've been making towards cleaner generation and transmission to bring that cleaner generation to market has helped us to achieve some pretty, I think, impressive goals and standards. Certainly here in Nova Scotia and now with that same focus and same great progress also in Tampa.
All right. That's perfect. Thanks, Scott.
There are no further questions at this time.
Great. Well, thank you all for joining us for this morning's call, and we'll look forward to speaking with you again next quarter.
This concludes today's conference call. You may now disconnect.