Ladies and gentlemen, thank you for standing by and welcome to the Pembina Pipeline Corporation 2020 fourth quarter results conference call. At this time, all participants are in a listen-only mode. After the speakers' presentation, there will be a question-and-answer session. [Operator Instructions]. I would now like to hand the conference over to your first speaker today, Mr. Cameron Goldade, Vice President of Capital Markets. Please go ahead, sir.

Thank you and good morning everyone. Welcome to Pembina's conference call and webcast to review highlights from the fourth quarter and full year of 2020. On the call with me today are Mick Dilger, President and Chief Executive Officer, Scott Burrows, Senior Vice President and Chief Financial Officer, Jason Wiun, Senior Vice President and Chief Operating Officer, Pipelines, Jaret Sprott, Senior Vice President and Chief Operating Officer, Facilities and Stu Taylor, Senior Vice President, Marketing and New Ventures and Corporate Development Officer. I would like to remind you that some of the comments made today may be forward-looking in nature and are based on Pembina's current expectations, estimates, judgments and projections. Forward-looking statements we may express or imply today are subject to risks and uncertainties, which could cause actual results to differ materially from expectations. Further, some of the information provided refers to non-GAAP measures. To learn more about these forward-looking statements and non-GAAP measures, please see the company's Management Discussion and Analysis dated February 25, 2021 for the period ended December 21, 2020, which is available online at pembina.com and on both SEDAR and EDGAR. Before we discuss the fourth quarter and annual results, I would like to first turn things over to Mick to make some opening remarks.

Good morning everyone. Thanks Cam. With our fourth quarter release yesterday, we are happy to close the book on 2020 and looking forward to a better 2021. In a very challenging year, I am proud of what we were able to deliver. From the beginning of COVID-19 pandemic, we were steadfast in our assertion that we would remain within our pre-pandemic 2020 adjusted EBITDA guidance range. In the face of numerous pandemic-related challenges and lower commodity prices, we took the difficult but necessary steps to do just that. Thanks to a resilient business model that protected our top line revenue and a focused effort to reducing operating and administrative costs, we were able to deliver annual adjusted EBITDA of nearly CAD3.3 billion, or 97% of the midpoint of our range. As always, Pembina takes great pride in consistently doing what it says it will do. If there is a silver lining to be found in 2020, it would be the clear validation of our long term strategy, diversification efforts and steadfast commitment to the company's financial guardrails. The resilience, stability and predictability of Pembina's business were once again proven, as they were during the 2009 financial crisis and 2015 commodity price downturn. I am equally proud of what we achieved for our other stakeholder groups. The health of our employees and communities has been top of mind throughout the pandemic. I am pleased to report that the company has not experienced any operational disruptions to its assets as a result of COVID-19. And despite all the new pandemic-related risks, Pembina had its best safety record ever in 2020. Further, we took all the necessary steps to limit the spread of COVID-19 within our communities while fulfilling our role as an essential service provider. At the outset of the pandemic, we…

Thanks Mick. Pembina reported record adjusted EBITDA in the fourth quarter of CAD866 million, which represents a 10% increase compared to the same period last year. The increase was primarily from the assets acquired in the Kinder acquisition, new assets being placed into service in the pipelines and facilities division and higher deferred revenue recognized on the Peace Pipeline system. We also benefited from monetizing a portion of NGL storage positions built up during the second and third quarter of 2020 as well as lower operating expenses in pipelines and lower general and administrative expenses. This was partially offset by lower margins on crude oil sales and a lower contribute from Alliance Pipeline due to a narrow AECO-Chicago natural gas price differential. Pembina recorded a net earnings loss in the fourth quarter of CAD1.2 billion due to non-cash after-tax impairment charges of CAD1.6 billion on Pembina's investments in Ruby, Jordan Cove as well as CKPC. Excluding impairments and associated deferred tax recovery, earnings in the fourth quarter would have been CAD338 million compared to CAD365 million in the fourth quarter of 2019. Total revenue volumes of 3.6 million BOE per day in the fourth quarter were up 1% compared to the same period last year. The positive contributions from assets acquired in the Kinder acquisition and new assets coming into service were partially offset by lower volumes on other systems, due primarily to lower interruptible volumes on certain pipeline assets as a result of lower commodity price environment and lower volumes in certain facilities assets due to lower supply volumes, scheduled turnarounds and COVID-19 related factors. A strong fourth quarter contributed to solid results for the full year. 2020 adjusted EBITDA of CAD3.28 billion was 7% higher than 2019 and within our pre-COVID guidance range. 2020 adjusted cash flow from…

Thanks Scott. I would like to take a moment to provide a few comments on the topic of ESG, which is playing an increasingly significant role in all areas of our business and our strategy and is linked directly to Pembina's long term value. First, following our inaugural report issued in 2018, this past December, Pembina released its 2020 sustainability report. The report includes enhanced disclosures on emissions, water, waste management and workforce. I am very pleased with the evolution of our reporting and look forward to continuous improvement in future reports. In addition to reporting, Pembina advanced other significant developments. We appointed Janet Loduca as General Counsel and Vice President, Legal and Sustainability. With over 30 years of legal, environmental, regulatory and sustainability experience, Janet is a strong addition to our team and I am confident Pembina will benefit greatly from her contribution. We also progressed strategies to reduce greenhouse gas emissions intensity. By the end of 2021, Pembina will have taken concrete action within the year as well as published five-year emission intensity targets. We made progress on numerous inclusion and diversity initiatives, including setting targets for both Board and executive levels. Starting in 2021, a significant component of Pembina's short term incentive plan will be tied to ESG metrics. I am going to stand shoulder-to-shoulder with our customers and peers in ensuring Canadian energy is developed and delivered responsibly with leading ESG standards and practices in place. We are proud provider of the services that get energy to where the world needs it and remain well positioned to support the growing use of natural gas to reduce global GHG emissions. Our proximity to Asia and its growing energy demand represents another strategic opportunity. Further, Pembina has many of the core competencies needed to adjust to the changing energy mix and is positioned to provide infrastructure services for new forms of energy or carbon sequestration and how it might facilitate hydrogen production. As with everything we do, we will move forward prudently, ensuring we deploy capital as we always have by making our existing business more valuable, adhering to our financial guardrails and in service of all of our four stakeholder groups. In closing, Pembina proved once again in 2020 that we are resilient, we are agile, we are safe and we are reliable. Pembina led our industry with a decade-long run of outperformance prior to 2020. Following a pandemic-driven pause, we will continue again working hard for another 10-year run. We anticipate 2021 to be a turnaround year with a return to a more traditional growth trajectory in 2022. We will not waver in our commitment to long term value creation that benefits each stakeholder group and we are optimistic about the future and the many opportunities in front of us. With that, we will wrap things up. Operator, please open the line for questions.

[Operator Instructions]. Your first question today comes from the line of Jeremy Tonet with JPMorgan. Please proceed with your question.

Hi. Good morning.

Good morning Jeremy.

I just want to revisit, I guess, the guidance a bit here and how the environment stacks up now versus maybe when you created it in November or so? And just wondering if you could quantify maybe a bit more how the commodity price environment looks now versus then and how producer activity and outlook looks now versus then? So just trying to see kind of, it seems like things have gotten better and just want to see if we can kind of quantify a bit more of the degree of how much it might have gotten better?

I will start and then turn it over to Scott or others. It's a good start, Jeremy. I don't think too many people thought we would be at $60-plus WTI and terrific propane prices, better gas prices. We are seeing some of our producer customers alongside the consolidation. We are seeing their stocks doubled here in the last three months or tripled in some cases. And so I am watching release after release, they are meeting their debt reduction targets and putting away some money. And we think that will turn into drilling later in the year, cautious drilling, I would say. And so obviously our marketing business is outperforming early in the year what we had in the budget because we budgeted it at lower levels. We see volumes slowly coming up in some places. But I think it will be later in the year before we can determine whether producers have the confidence to start drilling more. And when that happens, that's really when we get the torque, right, because we have got a lot of capacity ready and waiting. And as volumes grow, because we are covering our fixed cost anyway, that will go straight to the bottomline and we will have a lot more confidence, I think, a few months from now. But we are delighted with the start to this year. It is much better than we had originally forecasted.

Yes. Jeremy, maybe just a few tailwinds. Obviously, the stronger crude price and frac spreads, both are up pretty material from the time that we set our budget back in November. Crude is up close to 50%, hedge or the frac spread is pretty close to that same amount now. Again, we always caution people that we are at 50% hedged on the frac spreads, so we won't participate fully in that upside. In terms of some of the headwinds, FX has moved in the wrong direction. So, the Canadian dollar is now at CAD0.80. At the time of budget, we were at about %0.75, or $0.74. So that's a bit of a headwind. And the Chicago-AECO has continued to drift down from the time that we set our budget. So we do have some headwinds in addition to the tailwinds. But overall the tailwinds are definitely more positive than the headwinds.

Got it. And maybe just kind of building on that for marketing. There was a lot of winter storms last week brought in a lot of volatility to commodity prices there. Just wondering if that had any impact on your businesses? And if that, how that might have impacted your Aux Sable contract?

Yes. I mean, we participated in some of that, Jeremy. I can't pullout specific numbers. But again, we are pretty cautious on how we take advantage of commodity volatility. So I am not going to say windfalls, but it was definitely positive for us.

Got it. Maybe just a last one as far as producer activity, just wondering if you have a sense for rig activity on your footprint now? Or what your expectations are for where that could trend over the course of the year? And maybe how that has changed versus original expectations?

Good morning Jeremy. Jaret Sprott here. Rig activity actually in the areas, we pride ourselves in building our assets in the areas that have great resource, obviously. And in that particular area, we are actually seeing rig activity equal to or slightly above where it was kind of December of 2019, pre-pandemic. It's obviously great for the industry to see the activity coming back in. But when you dissect it down into some of those specific areas in which we have a very large presence, it's looking really good compared to the pandemic in March.

Got it. So you said rig activity ahead of December 2019 already? Just want to clarify that point.

Equal to. You have to get very specific down into some of our individual assets. But on a whole, the Northeast BC area of Veresen Midstream in that area, it's very strong. And then as you move into the Kakwa, Pipestone, Wapiti areas of the liquids-rich Montney continues to be very strong where we also have a very large presence. And then with the acquisition of Jupiter by Tourmaline, Jeremy, obviously, Jupiter was a great operator. We liked working with them. Tourmaline is a great operator as well. And we are really looking forward to them bringing their expertise into that Deep Basin Cretaceous where we also have a very large presence.

Got it. That's encouraging. I will stop there. Thank you.

Your next question comes from the line of Matt Taylor with Tudor, Pickering, Holt & Co. Please proceed with your question.

Yes. Thanks for taking my questions here, guys. If I could just start off on capital allocation. Do you mind clarifying your growth comments a bit because in my sheet it looks like you have got brownfield growth that still have the contracts in place you could turn on. But it seems messaging as you have the ability to self-fund at the lower end of guidance and then the flexibility if you get to the upper end. So it did seem like growth is there that can be turned on if customers need the capacity but you can bring down leverage or buyback stock, if not. Are you guys thinking about it a different way in terms of thoughts on capital allocation?

So Matt, I think as we have tried to reiterate, the first priority is obviously the dividend and capital to growth projects that fit within the platform, brownfield, greenfield expansions of the existing assets. So if those expansions, both Phase VIII and IX and Prince Rupert expansion continue to progress through this year, probably our first priority is to re-FID those projects and bring them into service and then after that, look at debt repayment and share buybacks. Now if those projects come back into service, we are not really spending capital on those projects in any material way until late 2022 and those will be spread out over a couple of years. So even in those scenarios whether those projects come back online, depending the timing of that, we should be in a position to generate potentially free cash flow and then we get into the discussion, again, of what to do after that. And again, after we have made those decisions, really we will look at where we are within our financial guardrails. If we are below our debt metrics on our financial guardrails, we will likely allocate that capital to debt repayment to ensure we are firmly within those guardrails. If we are within the guardrails then we are going to have to look at where the share price is trading in our view of intrinsic value and opportunistically buyback shares or continue to pay down debt to position ourselves for future growth as well.

Yes. Thanks for that Scott. Just to dig down a little bit more than, I mean if you are turning on these growth projects, it seems like Peace VIII and IX, you said they still have contracts in place. So it's not as if you are looking at projects that aren't backstopped by customers. Is that fair?

Yes. I mean, we can turn them on. When we need them, is really the question. So like with Phase VII, we do work collaboratively. I mean, we are not the kind of company that gives you something you don't need. And so with Phase VII, we surveyed our customers. There is not ever a perfect consensus and I am going back a year and people said, I know we are committed, I know you could build but we would sure appreciate if you delayed a year because we just don't need the capacity and we are using that kind of a collaborative approach in Phase VIII and IX to time that appropriately. And with Phase VII, when we first deferred it, it wasn't the best thing for Pembina in a way because it kind of took away from our growth. But we came back and we lobbed a CAD150 million off of that project through working with our customers and in scope and cost. So it wasn't all bad. I mean we are coming out with a better project and our customers really appreciated the pause. And when we get the signal, we will turn VIII and IX on and we think that signal is going to come, second quarter timing and hopefully that will give us a consensus to resume in the third quarter.

Great. Thanks Mick. And one more, if I may. On Ruby, given the write-offs this quarter and challenged outlook, do you address the liabilities on that asset? And if there needs to be free cash flow directed to it, is there a willingness to do? Just looking at the financial statements, it look like on a net basis it's about CAD39 million of current and CAD464 million of non-current.

Are you talking about the data at the Ruby level, Matt?

Yes. Exactly.

Yes. Well, I mean I think as starters that's non-recourse debt. I would just remind everyone that it's non-recourse debt. So we have the flexibility to make some decisions around what to do there. I mean, at the end of the day that asset is challenged. There's no doubt about that when you look at where the spread is. And I think it's too early in the process to comment on that other than to say that all parties involved here are going to have to come to the table to come to an agreement in order to make this a viable asset.

Okay. Thanks Scott. Thanks for taking my questions.

Your next question comes from the line of Linda Ezergailis with TD Securities. Please proceed with your question.

Thank you. Just to follow-up on Jeremy and Matt's questions. You have hit the play button again. Lots of opportunities in front of you. Some might be opportunistic. Lots of change going on beyond ESG considerations evolving, including the recent U.S. Presidential elections and some other political and regulatory dynamics. What's the appetite for M&A? And what areas would be the most compelling for you, if you had some choice? And how do you balance that with respect to some of the other priorities?

Yes. I will start with the macro, Linda, with that question. I mean, Biden came in and most people were predicting that and we were on record some time ago talking about Advantage Canada in that scenario and we believe that to be the case looking forward. Commodity prices has surprised us to the good. So delighted about that. Trans Mountain keeps moving forward. It looks like Line 3 will go KXL. It looks like it's definitely suspended, I would say. But that's still a million barrels a day of new egress and that oil isn't there today. And we have got Shell LNG. With the cold weather, both continentally and elsewhere, I think it's reminded people that hydrocarbons will play an important role for a long, long time. And that if you zoom into the Shell LNG project, there's lots of talk that the two Bcf a day currently under construction might turn into four Bcf a day and that's a huge number, a million barrels of oil and two to four Bs a day of gas, those are huge numbers and those will pull on this basin and this basin is ready to respond. It's not going to have some of the same headwinds looking forward that it did in the past. I mean we were behind a portion pipe which drove our pricing down. We could not access international gas pricing or international oil pricing and Brent is always $5 a barrel roughly, give or take, higher than WTI. And we will be on tidewater as a basin. And so we think Advantage Canada for the foreseeable future. And so now getting back to your specific questions. If we were going to do anything, we would be probably looking more Canada side than State side and we…

Thank you. And as a follow-up, you mentioned you could add pumping to Cochin. You recently announced an open season for that system. Can you talk a little bit more about what you are aiming to achieve there and how that would balance out? Any sort of increased domestic production, if there is a supply response to the added egress from Shell LNG and elsewhere?

Thanks Linda. This is Jason. So on Cochin, our first step of capacity evaluation is really around looking at what's there today and seeing if we can optimize it within the existing infrastructure that we have. So as we looked under the hood and got to know the asset, we moved all the operations to our control center up in Edmonton and we were able to find about 15,000 barrels of capacity on that line that we didn't expect in our acquisition model and we are continuing to look for more. So for our first step, we are really just looking to optimize the way the system is operated and see how much we can wring out of it from that perspective. In terms of what our vision is there, we think that there is still strong demand for condensate in the market. Obviously it's driving the drilling activity in Canada. But there's also the condensate or natural gasolines that come out from the U.S. they are price disadvantaged. So they use Cochin to come up into Canada. We think there is room for both the expanded capacity on Cochin and the incremental growth that we are expecting in Canada. And Mick touched on the incremental pipeline capacity that will come into service between TMX and Line 3. And those things are going to create a bit of a gap in terms of heavy oil production that can be produced in demand for condensate to use as diluent.

Yes. And just on your last piece about increased domestic. Yes, we believe, I mean, Phase VII, VIII, IX are about domestic increased condensate production. But we know that product will clear because it has to. And when we think about the basin as a whole, our shippers on Cochin are the consumers of the product. And we still, well, we have been saying this for years, this is nothing new. We think that Southern Lights is the swing volume and it will swing based on what happens on Cochin and what's captured domestically on Peace.

Thank you. And just as a follow-up. You already put some of the insights on the NGL dynamics. With the recent cold snap, I believe I recall on the last polar vortex you were shipping propane to Eastern Canada to help out. With the recent cold snap, if your export terminal were operational, would you be turning back barrels to help North American consumption? Or how do those exogenous cold snap shocks, would they affect any sort of propane export initiatives you would have in the short term?

I think when we look at turning on Rupert, we are going to have a wonderful a third, a third, a third balance, right. We are going to have exposure to Canadian markets, to U.S. markets and to, say, Asian markets. And today, if we were on today, we probably would be a third, a third, a third. And so I guess the answer is, we will go to the highest market. So we have capacity to go to the highest priced market. And the good news for our customers is that through our VWAP, our weighted average price basket, that they are enrolled in, they are going to participate handsomely in that equation. So if Bay is great, we are going to hit the accelerator to Bay and if Sarnia is great, we are going to hit the accelerator to Sarnia and if Edmonton is great, we can leave barrels domestically. And we have been saying to our customers and they have been patient with us that the time will come when they get, say, exposure and when we are using, we are amortizing the fixed cost of our storage and rail, which we had been under amortizing in the last number of years. I think our value proposition to our customers is going to be absolutely incredible here as we get into the second half of the year. And those shipping on Pembina's pipes are going to get a handsome reward compared to those that are not. Stu?

Yes. Linda, its Stu. Just to give you a bit of an update, we actually did take advantage and we looked through 2020. We actually cautiously watched our supply and our ability to move product. We delayed some sales through Q2, Q3 and had the opportunity to participate in better commodity pricing in Q4 and in Q1. And so our system, the logistic ability that we have and the growth that we are creating with the Bay markets, we will continue to have that. We will meet all of our commitments, but we have the flexibility to move the products around with our infrastructure. And we will be looking at that on a go-forward basis.

Thank you. I will jump back in the queue.

Yes. Linda, one last thing there. Just to recollect, we did turn on our Empress back which gives us the ability to swing those barrels anywhere. We can take those barrels South. We can take them, rail them East to Sarnia, if we need to. Or we can take them West. And so it's a whole bunch of more flexibility we have. Just because we have been doing this long enough to know we don't know when the next tight market will happen and where it will be.

Next caller please, operator.

Your next question comes from the line of Rob Hope with Scotiabank. Please proceed with your question.

Good morning everyone. I just wanted to follow-up on a prior question regarding the M&A activity. With CKPC being deferred until the future at some point, there is a potential to add some capacity with the process that's ongoing in the markets. Can you maybe talk about your views about being a JV partner in another project? Or is it just your existing project just on the shelf until markets improve?

We obviously aren't going to talk about an ongoing process. Right now, we are hunkering down. Like I said, we are focused on increasing our EBITDA dramatically without spending a lot of capital, investing a lot of capital. So filling up our existing assets, doing those really inexpensive debottlenecks, exporting products to Asia. And we have got a lot of running room within the most core part of our business. And so if you think about as concentric circles, getting more out of the assets we have is first, debottlenecking assets, like Jason talked about, Cochin or we have got many 100 million a day of capacity up in the Veresen Midstream footprint we need to take advantage of and petrochemicals is a concentric circle that's out from there. And it remains in strategy, but it's not our highest priority right now.

All right. That's very helpful. And then just in terms of those other projects that you are highlighting that you do have brownfield opportunities. Have your discussions with them accelerated over the last couple of weeks, last months, just given the commodity price environment? Or when you are looking at projects to restart, are you really going to focus on those ones that you highlighted in the MD&A first?

I would just say that when we made the statement in my remarks that our confidence in converting probable to confirmed has improved. That's how I would characterize it, as our producer customers, they are getting their mojo back. I mean, they just had the hell beaten out of them last year, as did we. And they have done their balance sheet repair. I think they are years ahead of their Southern partners for the most part in terms of living within cash flow, having good balance sheets and they are going to return, I think they are going to cautiously return to drilling within their means. They are not going to rely on capital markets to drill anymore. They are not going to borrow money. They are not going to issue equity. They are going to grow within their footprint. We have got the consolidation happening. And that, in my opinion, is going to turn into volumes and that's really what's going to power Pembina as we literally have hundreds of millions of dollars of EBITDA opportunity annually within our existing footprint. And that's going to get pretty exciting.

Excellent. Thank you.

Your next question comes from the line of Patrick Kenny with National Bank. Please proceed with your question.

Yes. Good morning guys. There's been some capital cost pressures across the pipeline industry of late and I know Phase VII is still trending on budget. But perhaps you can just comment on how your project is coming out as the outlier in a good way? And I guess looking ahead, if you do turn Phase VIII and IX on later this year, just if you are still comfortable with the initial budgets for those expansions?

Yes. I guess, recall that we had bought the steel for Phase VII pre-pandemic. And so I think we had, what, CAD300 million, was it, invested. And that represented the steel. So that's done and that worked out well. With KXL being cancelled, we have had a flood of interest in participating in our Phase VII project. And so we are pretty optimistic that we can meet or even possibly exceed the number we have out there. And with Phase VIII and IX, there could be cost pressures. But again, when you can deal with the contractor and say, hey, let's do VII, you bid hard on VII and then you will be at the top of list for VIII, IX, you can really get a great win-win with the contractor. Maybe their unit rates are lower but they have got a long fair way of working. So we are looking at not just costs with VIII, IX but also scope. And to-date, we are feeling not bad about it. Jason, anything to add there?

Yes. Patrick, I would add, because of the time that we have been allowed, the market downturn obviously was not ideal, but it did gave us time to evaluate our assets. And so having that extra year, we are able to really pinpoint where the capacity constraints are. And when we talk about what we historically referred to as Phase X, we are now able to actually test out our assets that we have put into service over the last number of years and figure out what they are truly capable of. So up until last year, we were just trying to stay ahead at the production growth and we weren't really able to plan as well as we would like to. We were just maximizing the amount of capacity we could add. So we are now able to actually look at specifically what areas need debottlenecking. What's the optimal pipe size, pump size? How many pumps do we need? All of those things. And we can actually stage it out in more stages now as we are looking. So we see a much more smaller stage series of expansions that we can do that are easier to execute and easier to plan.

And then just to round that out. I think it goes without saying, but I will say it anyway. Our ability to compete as scope and costs are managed, it's just getting stronger and stronger and stronger. I think unlike other news out there, you are going to hear our costs are going to go down, not up. Jaret?

Hi Pat. It's Jaret here. I just wanted to also add that you are fairly familiar with our map. Phase VII is essentially La Glace kind of going what we refer to over-the-top down into the Fox Creek area. And just the geographical footprint there, it's good terrain, right. You are not into like the foothills. Now if you think of going from Fox Creek going straight West and through picking up, say, Seven Gen's acreage and build it out to where our Musreau complex is, Resthaven Complex and moving up into North into GP, Grande Prairie, that's the really tough terrain, right. Those chunks of our assets, they are in the ground, they are built. Phase VII, it's farmland for the most part. Phase IX, you are up in that Dawson Creek, beautiful planes into Northeast BC. Once again very good. You do have some river crossings. But essentially, the tough sledding and building, it's in the ground. We don't have to go there anymore. So just keep that in mind as well.

Okay. That's great color. Thanks. And then Mick, maybe just to go back to your comments around ESG. And I know you are working towards establishing your carbon reduction targets by the end of the year. But just given we have seen a rapid increase in the number of large reputable companies pledging net zero by 2050, even without a crystal clear path to get there, but call it more of an ESG compass, if you will. So just wondering what's holding Pembina back from including net zero as part of your broader capital allocation guardrails?

What's holding us back is, we don't announce things like that until we know how we are going to do it. So when we announce it, we will know how to do it. You are going to see us taking concrete steps. And over the next number of years, I am going to make may be a bit of a bold prediction that when you extrapolate the sum total, three years from now into the future, you will conclude for yourself where we are going to get to. But we are going to put some targets out there. We will meet those targets. And we are going to put some evidence out there this year that we are serious about that. And I don't know when we will be able to predict carbon neutral. But when we do, we will know how to do it.

That's great. Thank you very much.

Your next question comes from the line of Robert Catellier with CIBC Capital Markets. Please proceed with your question.

Hi. Good morning folks and congratulations for managing through 2020. I know that wasn't easy. My question this morning is on ethane. I just wanted an update where you stand with that. Specifically, if you think the current incentives and government support that's out there is enough to sponsor a cracker? Otherwise, what do you think needs to happen for the industry to be in a position to a new cracker become a reality? And in your answer, maybe you can address the impact of CAD170 per ton carbon tax might mean to the outlook there?

Yes. Let's just start with the second question. I think anybody who comes in the province is going to have their carbon situation figured out as part of their base project. These are multi-billion dollar projects and add another CAD200 million or CAD300 million to sequester your carbon or do what you need to do. That's a kind of a rounding error. So I don't think that's a huge impediment for that. In terms of how we participate in that, we move most of the ethane in the province. So I can't imagine we are not going to be in the middle of that discussion and we will work very hard to facilitate it. Ethane is a huge part of our value chain. Some of our largest customers are ethane customers and it goes right back to the gas plant through pipe, through fracs, through storage and it's a 50-year demand. So we couldn't be more serious about that and we will do everything we can to facilitate it. And I think the government understands it too. That's the kind of value-add that Pembina and the province needs. Those are jobs that are going to last decades and decades and property tax base and so on and so forth. And they, in turn, can spawn value-added industries. So I think it's a logical place where we have sustained cost advantage as a province. And we think it's going to happen. Province wants it to happen. Stu, do you have any thoughts to add there?

No. The only thing I will add, Robert, is we have been looking at this, we think there are opportunities. There is definitely opportunities to increase the ethane supply competitively in Alberta to support the backstopping of a cracker. It's going to take producer effort, midstream effort and government effort. But I think there we are seeing alignment of those things. And so we are excited about the role that we play today and we think we can play a larger role in the future with the opportunities that are in front of us. Jaret, do you have any comments?

No. You guys said it well.

Okay. Thanks for that. And my last question has to do with the volumes at Younger. There is a lot of competing influences there. Obviously, a turnaround by also the drilling, but there is also some new services on the NGTL system in town. So can you help us and sort of attribute which of those factors has had the biggest impact on volumes? In other words, how much could be considered short term and how much is more of a long term impact on volume?

Rob, Jaret here. Yes, great question. In Q4, we did have a planned outage. So that impacted the Younger volumes. And you nailed it on the head. The supply coming into that area was altered with the start-up of some competing gas assets. I would say that, not divulging the exact numbers, but I would say that our marketing business team in conjunction with the gas processing team has done an unbelievable job getting back out boots on the ground and increasing the supply into that asset. So we did have a little bit of a hiccup there. And then with the planned outage, Q4 looked a little bit lower than normal, but the demand is picking up.

Okay. That's great. Thank you guys.

Your next question comes from the line of Andrew Kuske with Credit Suisse. Please proceed with your question.

Thanks. Good morning. In terms of risk management, I guess you have always been very good on knowing what you don't know. And the partnership you had with Kuwaiti was really representative of that. But maybe more broadly, how do you think about partnership or JV potential just in the context of on your business?

That's such an interesting question. We don't like to partner. Let me just say that. Most people know it. We like to control our own destiny. And the reason we like to do that is because most of the projects we do that extend the value chain, whether they are in our current suite of services or extend our current suite of services, they enhance the value of all of our assets. And when you don't control the next step of your value chain, then you lose control of taking the step beyond that. And so when we look at partners, we want to ensure that we are taking them to derisk what we are doing but also so that we don't impair our ability to keep growing along the value chain. And so for example, if we had no rail facilities, if someone controlled our rail facilities, we probably wouldn't have been able to do Prince Rupert because we would have an unknown in terms of cost and reliability between our Redwater frac and our Prince Rupert Terminal. And so because we own the pipes, then we were able to get into fractionation. Because we got into fractionation, we are able to control storage and rail and then we could push those molecules to Rupert and really because we wanted to. And so we can't imagine having a JV that prohibits us from taking the next step in the value chain. So we would like to have partners that we need to fill a gap, a knowledge gap, a capability gap, even a financial gap. But they can't impair our ability to control our walk down the value chain path.

Okay. That's very helpful. And then maybe just more narrowly on risk management. If you think about the efforts you have had specifically at Redwater with the co-gen, clearly we have seen a pretty volatile power market as the PPA has rolled off and we are in a more free market environment. Could you talk maybe a little bit about power cost management and how that's really benefited you and the outlook in the future?

Yes. I mean, just on co-gens, I wouldn't be shocked if we announced one a year for a number of years. I mean, they are taking us off a coal-gas mixture to an all-gas mixture. We don't have line losses through transmission. And so that's obviously energy going into the environment we don't need and very cost competitive. So we anticipate continuing to do that. We hedge power. Your question of risk management. We hedge a lot of our power, for example, at Empress because we hedge our gas, we hedge our power because those are the input cost of making propane and butane. And so we are doing that now. I would say, though, our focus is our self-supply power requirements, it' not merchant. Now we might end up with a few kilowatts of merchant just based on co-gen sizing. I am not going to rule that out. But our focus is self supply and that's a big market. We are one of the biggest power consumers in Alberta. And so that's a big market. We have economies of scale. Consistent with my comments on cost efficiency, we are consolidating all our power needs across our business to a single desk. And we will have our co-gens in there and we are looking at renewable sources of power as well, not necessarily to invest in but to consume. And so that's a big opportunity for us from a cost perspective and efficiency perspective. And again, we do hedge a lot of that and a lot of what we do is hedging our self-supply. Jaret?

Andrew, I will also add this on the mitigation side, not only the commodity itself or the energy that you are consuming, but as you build these co-gens you obviously have to back that up with reducing your reliance on the wires charges for the distribution, right. So as we build out this strategy, taking ourselves off because there is obviously potential that the energy itself increases in price. There is also the risk that the transportation distribution of that energy goes up. And we will continue to wind those portions of that exposure down as we build those centralized power generation units.

That's great. Thank you.

Your next question comes from the line of Robert Kwan with RBC Capital Markets. Please proceed with your question.

Perfect. Good morning. If I could just start some questions on the gas pipes. And starting with Ruby. You took the full write-off of the convertible preferred and recognizing there may be some interplay with that and probabilities around impairment. What is that saying if you are taking the full write-off against your expectations for future cash flow?

Yes. I think, Rob, obviously the impairment is a bit of an accounting exercise. There is lot to do on that pipeline. There are opportunities in the future. I think the main driver of the impairment is the short term outlook on that asset base is very challenged with both the Station 2 pricing as well as the Opal, Malin spread. There's just not enough sense in the spread to make that pipeline toll. So we do believe there is potential to re-contract that pipeline, albeit at much lower tolls. And longer term, we are looking at some opportunities around that pipeline. But that being said, there is a bunch of things that have to happen, including the no refinancing next year. So there are some things that are possible. Can you put that in an impairment model? No. So based on what we know today, that asset is very challenged. But we are working hard on that. And as I said previously, it's a bit of a complicated structure with ourselves at our preferred distribution. We have Kinder Morgan below what's the common and then we have the bondholders. And as I said previously, everybody is going to have to come to the table and work together to make this a sustainable pipeline. So in terms of the short term outlook, I mean, we had already forecasted a lower contribution from Ruby in 2021 and that was implied in our 2021 guidance.

Okay. But the fact that you wrote it to zero, you your expectation is there still is some positive cash flow here in the future. And depending on how the parties come together, it could still be a fairly material number into the medium terms. Is that fair?

Yes. I mean, there is still contracts, obviously, on that pipeline. One of the contracts goes out to 2026. There's also some interruptible volumes as well as the producer contracts are good for another six months. So there is cash flow on that asset. Where it ends up will be determined over the next several months here as we work with all the parties involved.

Yes. Robert, we think this thing is going to generate cash flow in the future. We can't point to it now. The foundational contracts were rich and they were struck in a different time. We think there is going to be replacement there. For an impairment test, you can't put what you think is going to happen in there. You have to put in what you know is going to happen with certainty. So I guess to some extent, the accountants made us do it. It's not necessarily reflecting what we think the long term cash flow generation prospects of that line will be. We do think it will have an ongoing source of cash flow.

Do you think we will get clarity on how this all plays out in 2021?

I don't know.

I will turn that to, let's let Cam answer that.

Yes. I think that it's early on in the process, Robert. So as Scott says, all parties need to come together. I think we are certainly hopeful that that's the case and we can have a constructive outcome.

Just turning to Alliance. Just some thoughts as to how you see that playing out over the next coming years? And do you see any potential to get the regulator more involved, either from rate setting or even just some of the mechanics around tolls? For example, do you think the regulatory environment right now is you are a price taker on the bid floor, but there is precedent from the CER for you to be a price setter to essentially incent contracting. Is that something you are looking at?

We haven't had that conversation yet. Obviously, that's a really volatile spread, to say the least. And I think the value of that pie, just at the macro level, Robert, was demonstrated. And it was a pretty important source of energy for the U.S. here recently. It was one of the pipes that kept producing. In fact, I think we saw 200 million, 300 million a day more hit that pipe here through the cold snap. And so you are going to have, I think, producers looking at that and you are also going to have consumers looking at that. Like, when the chips are down, we are with the energy. And so we think that that pipe will have a better differential than it currently does now. And we have seen this before. In my career, I have seen the spreads tighten up and then go to $2, above $2. And so we are pretty sure it will get recontracted. Maybe Pembina and Enbridge have to market the space a little bit in the near term. In terms of the rate setting, it's a very good idea. I am going to, well, it's a takeaway for us to see what the opportunities are. Maybe I can catch up with you offline on what you are brainstorm is there.

That sounds great. I will leave it there. Thank you.

And there are no further questions in queue at this time. I turn the call back to Mr. Dilger for closing remarks.

Well, thank you everybody. I am sure you are looking forward to 2021 as much as we are. Things are starting to break. It looks like on the COVID front, there's still some challenges ahead. Probably, having talked to our U.S. directors yesterday, they are ahead and things will clear faster than Canada. We see great energy prices. We are encouraged. We are not ready to say they are going to continue indefinitely, but it's a very good start. We are seeing volumes come up. And so, as we close the book on 2020, I want to say thank you to all our people on the phone, our shareholders who stuck with us through 2020 and our staff who were amazingly resilient and allowed us to meet our safety, financial and community objectives and our customers for working hard with us to keep paying the bills. So thank you very much and have a great weekend.

And this concludes today's conference call. Thank you for your participation. You may now disconnect.