Welcome to the Enbridge, Inc Third Quarter 2021 financial results conference call. My name is Polly and I will be your Operator for today's call. At this time, all participants are in a listen-only mode. Following the presentation, we will conduct a question-and-answer session for the investment community. Please note that this conference is being recorded. I will now turn the call over to Jonathan Morgan, Vice President Investor Relations. Jonathan, you may begin.

Good morning, everyone, and welcome to Enbridge Inc 's Third Quarter 2021 Earnings Call. Joining me this morning are Al Monaco, President and Chief Executive Officer, Vern Yu, Executive Vice President and Chief Financial Officer, Colin Gruending, Executive Vice President, Liquids Pipeline, Bill Yardley, Executive Vice President, Gas Transmission and Midstream, Cynthia Hansen, Executive Vice President, Gas Distribution and Storage, and Matthew Akman, Senior Vice President, Strategy, Power, and New Energy. As per usual, this call will be webcast, and I encourage those listening on the phone to follow along with the supporting slides. A replay of the call will be available later today, and a transcript will be provided on the website shortly after. We will try to keep the call to roughly 1 hour, and in order to get to as many answers to your questions as possible, we'll be limiting the questions to one plus a single follow-up as necessary. We'll be prioritizing questions from the investment community. So if you are a member of the media, please direct your inquiries to our communications team who will be happy to respond. As always, our Investor Relations team will be available following the call for any detailed follow-up questions. On to Slide 2 where I'll remind you that we'll be referring to forward-looking information in today's presentation and Q&A and by its nature, this information contains forecast assumptions and expectations about future outcomes, which are subject to the risks and uncertainties outlined here and discussed more fully in our public disclosure filings. We'll also be referring to the non-GAAP measures which are summarized below. And with that, I'll turn it over to Al Monaco.

Okay. Thanks, Jonathan. Hello, everyone. Well, to start off here, what you see in the photo is our new Ingleside Energy Center near Corpus Christi with the VLCC just being maneuvered in place for loading. It's an important investment for us on many fronts, so we'll come back to Ingleside in a few minutes. It's been a strong quarter operationally and financially. So Vern will take you through the results. By the way, Vern was recently appointed CFO. He's held a number of senior financial roles at Enbridge and most recently headed up our Liquids business, which Colin Gruending has taken over. I'll cover the high points of what's been a catalyst quarter and year for us, followed by a business update. Before I do that, though, let me speak to the current state of the energy markets. And as a reminder, our perspective on this is from a Company that's been focused on the energy transition for years. It's obvious we need to reduce global emissions and that we're moving to a carbon economy. And we think that existing infrastructure is essential to that transition. As you've heard us say before, we see ourselves as a bridge to a cleaner energy future by leveraging our businesses and by achieving our own emissions goals. We're transitioning our asset mix in line with changing fundamentals and building on our early mover advantage. And we end solar, hydrogen, and RNG. But it's also very clear that energy demand will continue to grow. And that economic growth will always depend on conventional energy. So squaring these two realities comes down to the pace of transition and ensuring we secure a low-cost, reliable energy supply while that happens. The realities of this careful balance are playing out in energy markets today. Stimulus spending and recovery are driving GDP growth. Oil, gas, and product demand are up and should outpace last year on the way to pre-pandemic levels. PetChem demand was resilient through COVID, but now even jet fuel has come back. As you've seen, natural gas demand is extreme, particularly in Asia and Europe. So consumption is up, and supply disruptions and tight inventories are creating an imbalance, and normally all of that is self-correcting by supply response. But this energy crisis that we're in right now is entirely about under-investment in all forms of energy, which is creating havoc with consumers, industrial competitiveness, and inflation. Higher energy prices are impacting consumers in developing countries. Spikes in electricity prices, heating, cooking, and filling up the tank. Higher industrial feedstock costs also impact competitiveness. And again, that rolls out to the consumer. So agriculture, manufacturing, pharmaceuticals, transportation, components, technology, and housing. Supply issues are impacting reliability with rolling blackouts and rationing in China and India, increasing coal power generation of all things in Germany, fuel shortages in the UK, and in the U.S. Northeast, gas generation is running at five-year highs. We're seeing a switching to fuel oil for electric generation. All of that to say the energy transition is a reality, but we need to be thoughtful about the pace and execution with the consumer in mind. And it's clear, if it wasn't before, that conventional energy will be a critical part of the supply mix for a long time. So the point being here, that the transition needs to be driven by a mix of balanced policy solutions. Most important in our view, we have to embrace natural gas because it's simply the enabler of building more wind and solar supply, among other things, and it's a great source of reducing emissions just like it has been to this point. Incentivizing consumption-based, economy-wide emissions reductions and efficiency measures and an immediate focus on regulatory certainty and support for CCUS investment. So onto the Q3 highlights. Operationally, all of our systems ran near capacity and that drove solid numbers. We're on track, as you saw in our release, to deliver EBITDA and DCF per share within guidance. The balance sheet and financial flexibility are strong and will move to the lower end of the target leverage range next year. It was a big quarter execution-wise, with $8 billion going into service, which will drive 2020 cash flow. And that's a great outcome in the face of a difficult permitting environment, to say the least. We also accelerated our U.S. export strategy and lower-carbon opportunities. So all-in-all, good headway on priorities, moving the ball down the field, delivering good results, getting projects in the ground, and building our business for the future. Moving to the business update beginning with liquids and Line 3. A month ago now, we completed the U.S. segment, so we're in full operation for Western Canada to the Midwest. With that, we also brought on the Southern Access Expansion to 1.2 million barrels per day into Chicago. Line 3 has always been about modernizing our system, and to my earlier point, it assures Canadian and U.S. refiners have a reliable, low-cost feedstock, providing affordable energy for consumers and industry. Line 3 though, also set a new bar for execution in the field through world-class environmental measures, actively engaging with communities in a different way, and developing deeper indigenous partnerships, cultural, environmental, and economic. We still have work to complete restoration, but I'm proud of how our team brought this one to the finish line. With Line 3 in service, we'll earn the full $0.935 cents surcharge on all mainline barrels. Returning the line to full capacity sets us up for downstream expansion to the Gulf Coast. On Line 5, the existing line and the Great Lakes Tunnel are also about safe and affordable energy. The fact is Line 5 and the tunnel are essential to Michigan, but also the entire region and two Canadian provinces. We're doing everything we can to make sure people's critical energy needs are not cut off, like propane in the upper peninsula and jet fuel for the Detroit airport as just two examples of many. Independent experts concluded there's no practical alternative to Line 5 other than thousands of more rail cars and trucks, which leads to higher emissions and increased energy costs. Pretty sure people don't want that, in fact, that's what the majority of Michiganders are saying, with about 80% or so believing the cost of energy is important to them, and there's four to one support for the tunnel. But we've always understood the need to protect the Great Lakes, which is why we've gone to extra lengths at the streets, including continuously and independently verifying the entirety of the line, shutting down the line as a precaution in high wave and wind conditions, and applying the latest technology to monitor ship traffic to ensure there are no anchor drags. We've committed to build the Great Lakes Tunnel to reduce the risk to as near zero as humanly possible. We received the first tunnel permit last year, and we're working on the remaining two. So let's shift gears now to our export strategy. A few years ago, we had a point of view on the evolving global supply-demand fundamentals and the need to direct infrastructure to the Gulf to capitalize on growing exports. As you can see, the maps developed out; we've built a big presence in the Gulf. Our export strategies are entirely consistent with the energy transition, because North America is a low-cost sustainable producer of conventional energy. LNG exports can displace coal, which is going to be a big driver of lowering emissions in Asia. Our U.S. Gulf Coast strategy began with providing full-path access for Canadian heavy oil to the Gulf and establishing a storage and blending hub. We're bolstering our seaway dock capacity with our Houston oil terminal to provide expanded low-cost waterborne access. We've now built out our light oil export position. Gray Oak initially gave us contracted pipeline ownership into Corpus and Houston, and the Ingleside Energy Center now gives us last-mile connectivity to the light oil export path. Ingleside is North America's premium export terminal, transiting 25% of U.S. exports last year, with 15+ million barrels of storage and 1.6 million barrels per day of ship loading capacity. Ingleside checked all the strategic, commercial, and financial boxes for us. It sources crude from the Permian and Eagle Ford, connected by 3 million barrels per day of pipe capacity. It's VLCC-capable in its prime location on the Outer Harbor. Commercially, take-or-pay commitments fit the business model well, and it came at an attractive valuation, and we're very glad to have retained the operating team. Finally, we evaluate every new investment at Enbridge through an ESG lens and specifically, we need to see a path to net zero. Ingleside's new state-of-the-art facilities were designed to reduce emissions in the first place, but we're also moving forward with large inside the fence strategies that allow us to achieve net zero on scope 1 and 2 and contribute to scope 3 reductions. Now it's worth just delving a bit deeper into why this is a business for the future. It's clear that the Permian is among the most competitive basins globally. And its scale, low break-evens, and proximity to markets means it's essential in any transition scenario and a competitive supply source in meeting global demand for many years to come. Ingleside has the lowest basin to water cost structure of any export point in Corpus or Houston. And that's because our two VLCC berths can load at twice the rate of a Suezmax. We avoid lightering trips, which when combined with our Outer Harbor location, saves roughly five days of transit. We also have capacity to capture incremental barrels, and this is a big upside for us. We'll go after the low-hanging fruit first, which is to contract up existing dock capacity, which could add another 600,000 barrels per day of loadings. And then we'll build into the permitted storage that we already have and dock capacity. So another 5.5 million barrels of storage there and 300K of loadings. Lastly, as part of our transition lens, again, the terminal's location and open land make it an ideal spot for green fuel and carbon capture development. While we're on the topic of exports, Texas Eastern and Valley Crossing are nicely situated along the Gulf, which puts us at the center of the U.S. LNG build-out, and that pace should quicken now, given the global supply crunch. Not much doubt about gas's role in sustaining European and Asian economies displacing coal and building renewables. These fundamentals drive more demand pull on our systems. In just two years, our LNG volumes have doubled to one DCF per day and we'll add another half billion cubic feet with our Cameron Extension that'll feed Calcasieu this year. We've also built a nice portfolio of late-stage development projects totaling about $2 billion. Bill and his team are also executing a $5 billion secured capital program. $3 billion of that is targeted for in-service this year. We've just completed our two BC expansions for about 600 million cubic feet a day of firm to the lower mainland and U.S. northwest. In the U.S. northeast, we've put Middlesex and Appalachian to market into service. But again, as you all know, this region needs a lot more capacity to address reliability and rising energy costs. We're advancing our multi-year modernization programs, which will lower emissions and ensure the integrity of our system for years to come. But there's more opportunity beyond that. Our new partnership with Vanguard Renewables will develop RNG projects along our system. We're starting with eight projects where we'll provide the injection and transportation assets, and that should total around $100 million of capital. Onto our gas utility in Ontario. First, this system is not only critical to the heating market but also to meeting peak generation demand. In fact, the ISO's recent study, and I encourage everybody to have a look at this, makes it clear that natural gas is essential to Ontario's energy needs today and in the future. Our franchise also benefits from continued population growth, mostly from immigration. We're on track for another 45,000 customers there this year. Importantly, Ontario has also approved 27 new community expansions. We're planning to sanction new capital for those shortly. Overall, we're executing on $3 billion of utility capital through 2023, so great visibility there to rate-base growth. There's also lower carbon potential. We're developing a sound portfolio of RNG and hydrogen opportunities. On RNG, we've got three in operation and four in construction. Through the Walker Comcor JV, we're developing another 15 projects across Canada with more potentially in the hopper. On hydrogen, our green power facility was completed a couple of years ago and that proved out the technology and gave us great experience. This quarter, we expanded that facility and put into service the blend hydrogen project and that will move into our distribution network. The prize here, of course, is to make that happen across the franchise. Finally, to our renewables business and an update on European offshore wind. As you recall, we've got three projects in operation and now three in construction and several opportunities in development. Matthew went through that at Enbridge Day. Offshore France, we've installed 35 foundations at Saint Nazaire and another 45 planned through mid-2022. So we're on track for in-service there late next year. Later in the share Gillette Fecamp, we're building the foundations there right now and at Calvados, we're manufacturing substation components and subsea cables. These projects will add 1.4 gigawatts of capacity with in-service dates through 2024. In terms of development, we've got another 3 gigawatts at various stages, so we have good runway here as well. In North America, we're accelerating our inside defense solar self-power. We've put three facilities into service on our liquids and gas pipelines. And as you can see here, you get a feel for the proximity to our pipelines. We've now started construction on four new projects on the Lakehead and Flanagan systems. This phase will be in service next year and will lower our emissions and generate good returns. These projects compete for capital straight up with the rest of our business. Our existing behind-the-fence land, large power load, and renewable capability really give us an advantage in this space, and there's a lot of runways to grow at the compressors and pump stations that you see noted on the map here. So stay tuned for more. All of this is a great example of how we're using the skills that we developed in renewables over the last couple of decades in the rest of our business today. Last point, as part of our new energy's business, we've established a dedicated team to coordinate the strategy and allocate capital to the best opportunities. An important element of low carbon strategy in our view is partnerships, that give us access to technology, complementary assets, and skills. We now have amassed four partnerships which includes a recent one with Shell, where we will collaborate on a range of North American opportunities. And with that, let me pass to Vern to go through the financial results and the priorities there.

Thanks, Al. And good morning, everyone. As Al mentioned earlier, my 28 years at Enbridge has given me a great view of the business as a whole. I look forward to leveraging this experience in my new role as CFO. My focus will be sustaining our track record of disciplined investment and value creation, so don't expect to see any big changes from me. Today I'll start off my remarks with an update on our key financial strategies. Our balance sheet and financial flexibility are in really good shape. We're triple B high across the board. We've bolstered our balance sheet capacity by continuing to recycle capital at attractive valuations. Another $1.2 billion this year. We've increased our EBITDA through organic growth and continued cost reductions. This EBITDA growth provides even more financial flexibility. The resiliency of our cash flows is very strong, providing highly predictable cash flows year after year. This solid base along with execution on our capital program has us on track to deliver 2021 results within our EBITDA and DCF guidance ranges. The capital we placed into service this year will drive a lot of free cash flow growth in 2022 and beyond. We expect to have $5 billion to $6 billion of annual investment capacity beginning in 2022, which we'll be deploying in a disciplined manner. I will come back to this later. So our foundation is very strong and Q3 was another solid Enbridge-like quarter. All of our four key financial metrics are up year-over-year on strong performance across our businesses and continued cost containment. Adjusted EBITDA and DCF are up about 10% to $3.3 billion and $2.3 billion respectively. EPS is up over 20%. Mainline volumes were about 2.7 million barrels per day in Q3, reflecting strong demand for heavy crude in path 2 and path 3, which was in line with our expectations. Gas utilization has been great. For the full year, we're seeing the benefits of our rate cases kicking in. The utility continues to be strong. Its cash flows provide stability, and it's throwing off a lot of growth. Finally, our renewables business is performing in line with what we've been expecting. This strong operating performance across all of our core businesses has, however, been partially offset by continued weakness in energy services and the effect of a weaker U.S. dollar on unhedged revenues. In energy services, steep backwardation and historically narrow geographical basis have limited our ability to take advantage of pipeline and storage contracts. FX has been a modest headwind to our operating results. Although we are substantially hedged, this shows up as an add back in our eliminations and other segments. In terms of DCF maintenance capital, it was a little lighter than planned, with three quarters of good results in the books. We're well on track to achieve our full-year guidance. Let's turn to EBITDA. We anticipate strong asset utilization again in Q4. With Line 3 fully in service on October 1, we're expecting fourth quarter EBITDA contributions in line with our guidance of roughly $200 million. The mainline we expect to average just around 2.95 million barrels per day. The Moda acquisition closed this month, and it will be a modest tailwind in Q4, with the terminal's contracted volumes ramping up over the next 12 months. On balance, we are anticipating tailwinds and headwinds to be roughly balanced for the rest of the year. Energy services is expected to remain weak through 2021. We saw some warmer weather in October in Ontario which will negatively impact our utility outlook and a weaker U.S. dollar will weigh on our operating results, net of our hedges. Onto DCF. We expect lower interest expense on a weaker U.S. dollar. Timing-related delays to utility maintenance capital, and cash savings from higher U.S. tax pool utilization, roughly in line with the $100 million we outlined in Q2. As we move towards year-end, our focus will shift to 2022. Here's a few factors that will contribute to our forecast, which we will provide a much more fulsome review at our Enbridge Day call. First, the $10 billion of capital that we put into service in 2021 will drive higher EBITDA and cash flows. Ingleside volumes will ramp up in 2022, growing its EBITDA contribution. We're expecting strong utilization across all of our systems, including the mainline, and we expect 2022 volumes to trend to our Q4 outlook. The gas pipeline and utility businesses are expected to remain nicely utilized and capture rate increases. Our renewable projects will remain largely in construction through most of 2022, with St. Nazaire coming into service in the last quarter. In energy services, we expect losses to moderate in 2022, but we still anticipate a slightly negative contribution next year. Out of the money contracts will begin to roll off late in 2022 and early in 2023, so that will bring us back to our more normal positive run rate. Finally, relative to our 2021 plan, we expect FX to remain a headwind in 2022. As usual, we'll roll out our formal guidance for 2022 in December. The outlook for our balance sheet is similarly strong. We've just completed our 2021 financing plan, including $2.4 billion of sustainably linked bonds at historically attractive interest rates. Despite the full spending associated with Line 3 and the Moda acquisition, with only partial year EBITDA contribution, our year-end credit metric is expected to remain within our 4.5 to 5.0 policy range. So that's a good outcome. A full year of contribution in 2022 from this capital, and the Noverco sale proceeds will drive debt-to-EBITDA down to the low end of our credit metric range in 2022. That's going to provide a lot of financial flexibility and continue to support our BBB high credit rating. I'm sure you're wondering about inflation. So let me spend a minute on how we're thinking about it. Recall roughly 80% of our EBITDA has total escalators, or regulatory mechanisms that protect us. If we continue our cost management track record, this could actually provide a small tailwind for us. Our strategy to procure materials and equipment early has so far shielded us from any significant inflationary impacts today. Let's shift to how we'll deploy our investment capacity. In 2022, we anticipate $5 to $6 billion of annual investment capacity. We'll be disciplined in terms of how we invest this to maximize shareholder value. We'll provide more detail at Enbridge Day, but our big-picture priorities have not changed. Protecting our balance sheet remains our first priority, and we will ensure that we'll have plenty of financial flexibility and buffer. That includes continuing to evaluate opportunities for further capital recycling where it makes sense. We expect to grow the dividend rate up to the level of medium-term DCF growth with an eye to migrating our payout to about the midpoint of our 60% to 70% payout range. Our base businesses will continue to kick out $3 to $4 billion of organic growth opportunities per year with attractive returns. The next $2 billion will go to the next best alternative, and we will assess share buybacks, adding more organic growth, asset M&A, and further deleveraging. As we have said before, share buybacks have risen in the order of priority, and we continue to believe with the predictability of our cash flows, a ratable growth, our asset longevity, we are currently undervalued at our current share price. I'm excited that we have this financial strength and flexibility to optimize our capital allocation and shareholder returns. To wrap up, our annual Enbridge Day will be on December 7th this year. As usual, we will use this event to update you on our financial outlook and our strategic priorities. We're planning for the event to be in-person, so we look forward to seeing you there. Of course, we'll have a webcast for those wanting to attend virtually. With that, I will turn it back to Al.

Okay. Thanks Vern. Just a couple of takeaways here. 2021, as you've heard, is a pivotal year for us. The business is performing well and is generating highly predictable results. We're executing the priorities that we laid out at the last Enbridge Day. We're on track to put in $10 billion of capital into service this year that will generate a lot of cash flow as you just heard. So with that, let me hand it back to the Operator for Q&A, as we are not yet all in the same room here, so I'll direct questions as needed. So back to the Operator.

Thank you. We will now begin the question-and-answer session. And your first question comes from the line of Robert Kwan with RBC Capital Markets.

Great. Good morning. I just wanted to dig into the comments you made to start around capital allocation. Specifically that $2 billion back up. You had some comments just around share buybacks, can you see your shares as being undervalued? I'm just wondering whether you, similar to what you did about a year ago, be willing to rank order those options. As it relates to dividend growth, I think Vern Yu mentioned up to the underlying growth. I don't know if you can just frame that comment in light of what your friends across the street did this morning.

Okay Robert. I think on the capital allocation, it's fantastic that we have the capacity to look at all of these different options. Obviously, when we make these decisions, there's a number of pros and cons to each of them. On the share buyback front, it's great that we can invest in Enbridge. As the company continues to grow its DCF and its cash flows, a share buyback lowers our payout. It provides dividend savings, and obviously it's executable. But some of the cons are that it doesn't provide any further organic growth, doesn't add incremental EBITDA, and doesn't help us with our long and medium-term cash horizons. So I think what we'd like to do is look at that in concert with all of the other opportunities that we have. As we work through 2022 and beyond, we'll make sure that we make the best decision for our shareholders. If we turn to the dividend, obviously, dividend growth is a key component of our value proposition. We plan to continue to grow it, but we have some other competing priorities as well. In the near to medium term, we'd like to get back to the middle part of our policy range. At this present time, we don't believe the market's fully valuing the level of the dividend that we provide today. So hopefully that provides some clarity for your question there.

It's great, Vern. And if I can just finish with a question on the oil pipeline side with all three done. You've talked in the past about other oil pipeline expansions. Just wondering if there's any update on those now that Line 3 is in service and are any of these projects somewhat imminent but waiting and being held back pending clarity on the mainline contracting situation?

Hey Robert. Yeah, we're excited that obviously Line 3 is in service and immediately being useful and well utilized, and we do have a batting order of expansions, cost-effective ones by the way, lined up as we've talked about for some time. Our system is vast, complex, and it continually provides creative solutions that we can harness, as we have to the last number of years. These range from drug-reducing agents, horsepower on existing pipes, potentially some reversals, or even repurposing. So the same roster I would say that you're familiar with is being teed up here. It will be dependent on customer interest and I think in part, industry's emerging need to sustain some excess egress and multiple options to market. I think that's a concept that's been absent for a couple of decades and we'll do our best to fill that need. We'll talk more about this at Enbridge Day. That's what that day is designed for. But we are excited about the prospects here.

That's great. Thank you very much.

Hi, good morning. Well, I just want to start off with the Ingleside acquisition there. I know it's very recent since you guys closed, but just didn't know if you could provide any updated thoughts as far as now that you have it, how is it executing versus your expectations? More specifically, when we think about the crude oil export side, we've seen trends shifting there a bit given where the differentials are. So wondering if you could provide any more thoughts, I guess, and how you see those trending in the near term.

Yeah sure. Hey, Jeremy, yes. So we're pretty excited about this. The market for the Permian barrel is increasingly global, as you know, it's large and growing and it's going to play a long-term role in energy export and energy transition. We closed the transaction a few weeks ago. I know, but I would say our Q4 outlook and our '22 outlook is quite encouraging. We're seeing export loadings ramping up quite nicely in line with upstream drilling rig account trajectories. So that's good. I'd say it's also consistent with our purchase economics. We have multiple commercial expansion offerings in-flight to leverage the operating leverage that we've talked about and the fixed cost pre-built facility that's there. Some of these offerings are a continuation of commercial offerings that the prior management team and owner had in-flight and some additional ones on our own. We're looking at multiple types of products to export, and with that some good inbound interest, I would say here, right off the bat. So I think it's looking generally pretty positive here, Jeremy.

Maybe just to add, Jeremy, one point to that. Really in terms of your part of your question around differentials and where they have been flow, the way we look at this one is this is a highly contracted facility, so the way the economics work in our model is we've got that base. Then we look at it as upside if the differentials point our way and in the producers' way. Really, I think there's good upside here to global dynamics, which you know, are likely going to look for more low-cost, reliable light crude from North America. So that's just how we look at it in a bigger picture.

Got it. That's very helpful there. And then maybe just want to pivot to, I guess, energy transition side a little bit. RNG, it seems like it's quite active on the Canadian side, just wondering on the U.S. side, if you see opportunities there, or how much capital could be deployed in general.

Yeah. Jeremy, I think the Vanguard Renewables partnership that we announced is a really good step. We have line of sight to $100 million worth of projects in the near term. It's kind of a good place to dip our toe in the water and the model but we're setting up really, it gives us line of sight to even more. So like I said, toe on the water, really good stuff there. I think in addition to that partnership though, we've really got to think about our long-standing relationship with all of the LDC customers. So all of our utilities that you know are somewhat active in this space, and the relationship there could extend from partnerships to do some RNG projects together to just simply we do a project and have a resale to them as we both strive to meet our emissions target. I think it's got a lot of potential. I mean, how much is yet to be seen. It's pretty amazing when a place like the AGA comes out with a statement saying RNG could meet half the heating load, over the next... I forget the timeline, 10 or 20 years. That's pretty impressive.

Got it. Thanks for that. I'll leave it there.

Good morning. I want to understand energy transition and I'm wondering when you look at energy transition opportunities and you put them through your filter, you look at the risk reward. Would there be any significant difference in how you look at those investments this year existing portfolio? Is it different returns, different risk profiles, different counter prices? Will you comment on that?

Okay. It's open. So I would say it's exactly the same as we look at the rest of our business. As Vern referred to, we'll continue to be very disciplined as we're putting capital to work in the future. Maybe the way to think about this at a high level is if you look at what we have in flight right now. If you look at wind, solar, some initial RNG and hydrogen investments, they are pretty much right in line with the business model that you're used to seeing from us. In the case of hydrogen, for example, with the two projects that we're working on in Ontario and then a third one in Quebec, they'll be incubated, if you want to look at it that way, within the existing commercial model, where we're assured of a return on capital. I think that's the way we're looking at it. We've probably got $2 billion in flight now in terms of the energy transition category. Over the next five years, you're probably looking at that same level of call it a billion dollars a year. What’s to be determined though longer term is how fast hydrogen and other areas like CCUS develop. For the next five years, we don't see massive amounts capital being deployed there other than these core areas that we're working on right now. Hopefully that provides some context.

Can I make just a quick add on? The other thing that we're doing is, when we look at our traditional investments now, we do add the price of carbon to each of those investments, and we also increased the hurdle rates slightly because of the energy transition risks on some of those opportunities. So with the energy transition assets, obviously, those adders aren't applied.

Yeah. And again, I think you've seen the chart we use for this, Ben. The whole game here for us is to really utilize the existing assets to leverage those assets into low carbon opportunities. You see it in the utility, you see it in Bill's business, and you see it with the solar self-power which links right up to our conventional business.

Thank you.

Hey, Ben. We're waiting for this imminently, right? It's unclear precisely the form of the decision that will come. I think they have an array of choices here, but obviously we strongly believe in the one we filed for with the variety of benefits we included in it that were, as you recall, requested by industry. So we'll look forward to that. If the decision is acceptable, and I would emphasize this next to it, in its totality, we would proceed to the next stage, which would be commercial contracting and then finality by mid '22. If it's not acceptable, again, in its totality from a risk-reward perspective for our capital providers, we could refile for something else that would be. We've laid out some options there over the last couple of years, so I will have to wait and see Ben.

Good morning, everyone. I was just looking at Slide 23 and where you present the outlook in the preliminary '22 outlook. Although there's no number, I tried with my ruler to figure it out. But I guess my question here is that you sort of highlighted the positive benefits and negative benefits. Obviously the dollar and energy services, it's headwinds, but you sort of included Moda as well as the benefit of the '21 growth CapEx. I was wondering if you can sort of talk about any other tailwinds that you're seeing in your prepared remarks you talked about, kind of the energy crisis that's going on right now. Are there any inflation escalators tied to PPI and CPI that could potentially benefit Enbridge? Just curious what other tailwinds that we could be thinking about, where you could see some operating leverage within the existing system, not just with respect to the growth CapEx coming online?

Well, maybe I'll just try to go through this quickly. First of all, on your question around inflation, I think, as Vern mentioned, there's a very large majority of our EBITDA and revenue that’s driven by indexing of some sort that's off of inflation. So that's a plus. I think in terms of the commodity, part of your question, as you know, we're not hugely driven by commodity prices given our business model, but there are a couple of things around NGLs that we have, for example, at Aux Sable. Maybe there's a little bit of a tailwind with some excess capacity we might have in market gas to capitalize on that. I would say a big part of what we've been focused on in the last two to three years, is cost management, and that's not to be underestimated. Especially since every dollar you save is certainly very helpful from a balance sheet perspective. Those are the general categories of tailwinds beside the bigger ones that Vern mentioned.

Okay, great. Just to clarify before I ask my second question, there isn't Line 3 is bringing more volumes and part of your assets elsewhere we'll see benefits as well too, or?

I'm sorry. Could you just clarify that, Shneur?

It just the fact that like Line 3 replacement is now in service, that there would be more volumes flowing through that there could be more operating leverage elsewhere in the system?

Yes, I believe we are likely to operate at capacity now that Line 3 is in service, as we've planned. While there may be some minor benefits from additional volumes, they probably won't be substantial. The main advantage is that now that we have Line 3 operational, there are promising opportunities for expansion downstream. These will require very little capital, which is ideal for us at this stage of the cycle. We are positioned to benefit from these opportunities.

Yes, there have been changes, some positive and some negative. The industry still generally prefers to contract the line for various reasons. Total certainty has been a guiding principle for our agency over the past 25 years. After two decades of capacity limitations, the overview we have now is essentially an extension of the toll at the exit of our current agreement, and with toll discounts, it is actually lower for many. Therefore, we also prefer to contract the line. We are mindful of our vulnerabilities as we look ahead, especially with Trans Mountain coming online. This emphasizes our focus on balancing risk and reward, which we aim to optimize. We will carefully consider our decision, and if it proves beneficial, we will move forward. If it doesn’t, we will explore other options, such as a fixed tariff tolling system similar to what we've utilized for 25 years or a cost-of-service model that ensures cash flows are safeguarded.

And I was just going to mention on that last point, Colin, for Rob. The other way to look at this is what the shippers are actually not very excited about, which we've heard very clearly from them that cost of service is something they'd not prefer. There are issues with the commercial structure with an existing type of arrangement. So I think it's almost when you triangulate what they've really pushed for, which is contracting, we still think that's the best outcome for them and for us, and it's been driven home for as Colin said, a long time in discussion with industry.

Thank you.

This concludes the question-and-answer session. I will now turn the call over to Jonathan Morgan for final remarks.

Okay. Great. Thank you. Thank you, everyone for joining us this morning. As always, we appreciate your ongoing interest in Enbridge. Our Investor Relations team will be available following the call to address any follow-up questions you might have. But once again, thank you and have a great weekend.

Thank you. This concludes today's conference. Thank you for your participation. You are appreciated. You may now disconnect.