Good day. And welcome to the Pembina Pipeline Corporation 2021 Third Quarter Results Conference Call. Today's conference is being recorded. At this time. I would like to turn the conference. Friends over to Cameron Goldade, Vice President of Capital Markets. Please go ahead.

Christina. And good morning, everyone. Welcome to Pembina's Conference Call and Webcast to review highlights from the Third Quarter of 2021. On the call with me today, we have Mick Dilger, President & Chief Executive Officer, Scott Burrows, Senior Vice President and Chief Financial Officer. Janet Loduca, Senior Vice President External Affairs, and Chief Legal and Sustainability Officer. Jaret Sprott, Senior Vice President and Chief Operating Officer for Facilities; Harry Andersen, Senior Vice President and Chief Operating Officer for Pipelines; and Stu Taylor, Senior Vice President, Marketing and New Ventures and Corporate Development Officer. I'd 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 refer 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 November 4, 2021, for the period ended September 30, 2021, which is available online at pembina.com and on both SEDAR and EDGAR. With that, I'll now turn things over to Mick.

Hey. Thanks, Cam. Good morning, everyone. I'm very pleased with the strong results we delivered in the third quarter, reflecting continued robust pricing across all commodities and Pembina's value chain, including crude, condensate, natural gas and natural gas liquids. The current commodity environment is supportive of our outlook for 2021 and 2022, including an opportunity for Pembina to maintain an above average contribution from our marketing business next year. As well as strong pricing has positive implications for volumes on our existing assets, and the longer-term prospect for business. Including our backlog of currently deferred and potential new growth projects totaling more than $5 billion, with attractive returns. Since the onset of the pandemic, producers have maintained discipline with a focus on productivity improvements, debt reduction, cash-generation, and returning capital to shareholders. We remain of the view that the robust commodity pricing environment driven by the post-pandemic economic outlook, rising energy demand with a tight supply curve sets the stage for supply growth into 2022 and beyond. With services across the hydrocarbon value chain, Pembina is poised to benefit some of the growing sector activity. Coupled with strong financial performance in the third quarter, Pembina achieved another important strategic milestone with the announcement of our target to reduce the Company's greenhouse gas emissions intensity by 30% by 2030 relative to 2019 baseline emissions. The GHG reduction target will help guide business decisions and improve overall emissions intensity performance, while increasing Pembina's long-term value and ensuring Canadian energy is developed and delivered responsibly. To meet the target Pembina will focus initially on operational opportunities, greater use of renewable and lower emission energies, and investments in the lower carbon economy. In addition to the GHT target, Pembina expects to make further ESG progress with the announcement of a equity inclusion and diversity…

Thanks, Mick. Overall, Pembina reported strong quarterly results due to new assets placed into service and the rising commodity price environment. We reported adjusted EBITDA of $850 million for the third quarter, 7% higher than the same period last year. The primary driver of the period-over-period increase and adjusted EBITDA for the $75 million higher contribution from our marketing business, which continues to benefit from higher margins on NGL and crude oil sales, and a positive impact of higher market in NGL volumes. Marketed NGL volumes increased, as sales have returned to pre -pandemic levels compared to the third quarter of 2020 when Pembina built up storage positions due to lower commodity prices. As we saw in Q1 and Q2 of this year, the benefit of higher prices and volumes was partially offset by realized losses on commodity-related derivatives as part of our systematic hedging program. Excluding the impact of the realized losses on commodity related derivatives, third quarter adjusted EBITDA increased $127 million over the same period in the prior year, highlighting the potential of the business at current commodity prices. The quarter also benefited from new assets placed into service throughout 2020 and 2021 in our facilities division, including the Prince Rupert terminal and [Indiscernible], Duvernay III and Hike Developments. As well, we benefited from higher volumes at Garrison Midstream's Dawson asset, and on the Peace Pipeline System. Offsetting these positive factors with the impact of a lower U.S. dollar exchange rate, a lower contribution from Ruby Pipeline due to lower contracted volumes, lower revenue from Kotian Pipeline due to the impact of a timing difference in the recognition of deferred revenue, and higher general and administrative expense due to the higher long-term incentive expenses as a result of the change in Pembina's share price. Third quarter earnings…

Thanks Scott. With strong pricing, providing a steady tailwind for our business, we remain optimistic about the future as we continue to advance our ESG strategy and progress development of future growth opportunities. Finally, we remain on track to deliver full-year 2021 adjusted EBITDA within our guidance range of $3.3 to $3.4 billion and look forward to providing our outlook for the 2022 and the release of our guidance and capital budget in early December. We would once again like to thank all of our stakeholders for their support with that Operator will wrap things up and go to questions. Thank you.

Thank you. [Operator Instructions] We'll take our first question from Rob Hope with Scotiabank.

Good morning, everyone. First question on the Alliance re-contracting, [Indiscernible] a little bit of color here because the [Indiscernible] contracts expires at the end of October, so you had a big gap there. Did you just really re-contract those last two months? And then, I guess, as a follow-up there. Just given the strong demand you've seen, why not look to extend those contracts a little bit further?

Rob, I'm going to pass that over to Harry.

Hey, Rob. Good morning -- so to be clear, the contracts, there was a renewal at the end of October that for contracts that would expire in November 1st of 2022 for basically the 2022-2023 cash year. When Mick was going through his opening what we spoke about in terms of Alliance essentially being full for 2022 were the contract expiries that happened October 31st of 2020. So as we look at the 2021, 2022 gas year, Alliance is essentially full. For the 2022, 2023 gas year going forward, we are still in the middle of a renewal process and we expect to have further information by the end of the year.

All right, that's helpful. And then just taking a look at your LPG export terminal, we've been tracking [Indiscernible] Prince Rupert, seems to be very busy there. When we look at the potential expansion into Q1 of 2022, is this really just wrapping up engineering because you're at a high utilization? And then secondly, what about moving other products that are there rather than just propane.

Jaret.

Good morning, Rob. Yeah. Essentially, we're just wrapping up and getting to Class-3 estimates on the expansion, so doubling the capacity and moving to the medium gas carriers, so essentially doubling the cargoes that we can move through there versus the handiest right now. And we expect to make that decision in Q1 of 2022.

Thinking that you have enough propane export, so you don't need to touch Q2?

We're looking -- we'll eventually look at Butane right now. The focus is on propane and so maybe -- I think it'd be interesting to listeners just to talk about the markets we've had and the positive feedback we've gotten on our product quality.

Thanks, Mick. Rob, pardon me. And so we've had that, we've been up and running since April. Really happy to report the logistics coordination from our RFS facility, the rail loading, and we've moved 5,400 railcars to our PRT site. We've moved 3.3 million barrels of propane through the facility in that -- in the nine-month period here, essentially. And we're really excited about the future and the growth, we've got cargos into Japan, South Korea, China, and Mexico, and we did our commissioning cargoes into Hawaii, and so we're really happy with where the destinations have -- we've been able to penetrate or move that into the market. One of the things that we're excited about is again, our operating teams were producing a low ethane, propane and in particular, we have a very exceptionally low methanol content, which is rare, unique for us. And we're producing, what I'd like to refer to as Pet Chem quality propane at our RFS facility that allows us -- we're getting great feedback on the quality of the products that we're loading, and we believe that opens up premium markets on a go-forward basis.

Thank you [Indiscernible] I will jump back in the queue.

So to our next question from Patrick Kenny, with National Bank Financial.

Hey, good morning guys. Maybe just on the Dow opportunity. Could we get your thoughts on when you might need to expand the [Indiscernible] system, perhaps vantage, and also, does it make sense to strip off some ethane from Alliance at Fort Saskatchewan? Just trying to get a better sense on how you're thinking about feeding Dow that incremental supply over time.

Hey, good morning, Pat. I'm going to just make a quick comment, then turn it over to Jaret. As you know, we have ethane extraction assets all over the province, so we're just sorting through the portfolio. And frankly, the diversification that our customers are asking for, they're not asking for just 1 source, they want diversified -- geographically diversified products for obvious reasons. So they're putting billions into the ground, and they don't want to be beholden to 1 supply source. So, Jaret, maybe you can add some color. Thanks.

You, bet, thanks. Good morning Pat, like Mick said, so we're currently evaluating all of the pipelines that feed our current customers Pat, so between [Indiscernible] and vantage and the peace system, etc. and evaluating the Redwater complex on where do we need to expand to provide our customers with that diversification that Mick talked about. They want to ensure that the C2 molecules, their feed stock are coming fro m a variety of sources. So we're working through that right now. With respect to [Indiscernible]. Oksavo (ph) does have the contractual rights to straddle the Alliance Pipeline and extract ethane volumes outside of our Shanahan facility at the end of the pipeline. And working with our fantastic partners over to Enbridge. We're currently evaluating that as well to not only satisfy existing demand, but also as part of the new expansion that potentially might be coming for the province.

Okay. That's great. Thanks for the color guys, and then just maybe a quick follow-up on Alliance. But more from a longer-term contracting perspective, curious to get your thoughts on how you build out that asset as a conduit to the Gulf Coast. Is this more of a greenfield initiative or look at M&A, more strategic partnerships downstream? Thanks.

Pat, it's very insightful question -- it's like you're giving us tips on what to d o next, but -- thanks for that. A bunch of this gas is making its way to the Gulf Coast and with $20 plus in [Indiscernible] product, you can imagine why and as [Indiscernible] told our board yesterday that there's a better part of 10 [Indiscernible] a day of new export capacity being developed on the Gulf Coast and until more things happen, like our heater LNG projects, albeit that goes to Asia. We think there's going to be a continued desire for shippers on Alliance to get to the coast. And certainly that's caught our attention, so that is under review. And I think some of the -- Harry mainly touched on the shorter-term contracting, but there's also a very robust activity for longer-term contracts interest underway, and I'm quite certain some of that has to do with Gulf Coast exports. It took us a few years to digest Alliance. I think there is possibility with Alliance to really put a lot of gas into that line, and to look downstream as we have for -- where does the ethane go, where does the Propane go, where does the Methane go, and keep our vertical integration going downstream? And I know [Indiscernible] looking at that.

Great. Thanks Mick, I'll leave it there.

I will take our next question from Shneur Gershuni with UBS.

Hi. Good morning, everyone. Maybe just wanted to start off on the marketing business and how you're thinking about it for 2022. Quality prices have obviously changed dramatically over the last 3 months to 6 months, the frac spreads have opened up as well also. Do you expect to continue a hedging program and would it be programmatic in heat, in nature? Do you sit there and watch it and see where this market is going? Just trying to get your thoughts as to how you're thinking about the hedging strategy for next year.

The thing about hedging is it's only hedging if you do it with regularity and consistency. So in terms of trending, we said in the notes that we're quite, or very optimistic on what can happen next year in marketing and that is across the board. We also said in the piece that all commodities are doing well and I think you're seeing our customer quarter releases are jaw-dropping and possibly even better in the fourth quarter. And so when they are making money across all commodities, it certainly helps us to make money and the differential pricing that we need to have really good outcomes is in place today. So, it's shaping up good. And I think we're -- we've taken some risk off the table, and we intend to follow our normal process, because you're never absolutely sure what Mother Nature will do in a warm winter or something unforeseen can upset the differential pricing in a hurry, because many of our [Indiscernible] depend on more than one commodity, as you know, and so we have to be cautious. We do intend to keep following our systematic program of hedging.

Great. That makes perfect sense. Maybe if we compare it to the CCUS project that you announced earlier this year that you were exploring. As part of the conversation or announcements at the time you talked about re-purposing pipeline and so forth. There's been similar discussions in the U.S. and Texas and so forth, and the conversation seems to always show that -- or the pushbacks rather have been that, CO2 pipes are very different than other pipes, need a thicker steel wall and pressure and so forth. I'm just wondering, are the pipes different that you're planning to re-purpose? Is it a scenario where it's more you have it right away when you plan to replace pipe? Just wondering if you can give us a little bit more color or thoughts on how this will come to about from a capital perspective.

Yeah, I'll start out and then I'll kick it over to Stu. There's a couple of things. Number 1, we're looking at a combination. In certain circumstances, we have the right away, but to your point, we don't have the right pipe. Let's say we have an oil pipe and a right away, that's not going to have the pressure capability that we need to move CO2. And so that's a situation where we could pull aligner or high pressure pipe within the pipe. That's under review with the regulator, our ability to do that. In places we do have high pressure gas pipeline, We've done the work and we think those pipelines can be retrofitted -- they need some work, they need cracker esters put in. But, the big difference between Alberta and Texas is it's damn cold up in Alberta, and it's cold and the ground temperature remains very cold. And so that is a fundamental tailwind we have and most of the time or complaining about it this might be the one time that it's actually a positive and it keeps -- it keeps that CO2 in check. Maybe Stu, you could elaborate a little bit where we are on the process there and also what our critical path is to take that project off the drawing board and to make it real.

Sure. So -- and again, I think we'd have a vision and as described, we believe there is an advantage to our gathering systems that we have. And there you've highlighted, is it rights-of-way or is it pipelines? We also believe, as a pipeline operator, that we have expertise. We move high-pressure pipelines and products. We do appreciate the difference that CO2 is and we're working exceptionally closely with industry experts. As Mick described, I think you're going to see, as we come forward, that we will be building some new pipe. We will be putting liners in other pipes and retrofitting some of our pipes, all in an attempt to be -- to provide a CO2 solution at the lowest possible cost. We recognize -- we will be working with others, collaborating on how to do that where the emissions are going to come from. And so we're working hard. We are part of the government of Alberta's process on the carbon sequestration right that that part of the government is working through. We're working with the government, with our partners -- extensively with our partners on how to proceed. And we're excited about the progress -- we've got experts helping us along the way. And so, as the government's described, we're hoping in early 2022 that the sequestration permit process will be through and the government will be making some decisions on who will have the rights to sequester products in Alberta, We believe we have a strong solution, an industry solution to capture a lot of the emissions in Alberta, and working with customers and the government to progress that path and that process.

That makes perfect sense. Really appreciate the technical answer there. Thank you very much, and have a great weekend.

You as well. Thank you.

And we'll go to our next question from Robert Kwan with RBC Capital Markets.

Good morning. Just start with how you're characterizing the nature of the discussions you're having with producers. as you noted they're holding, or they're maintaining a lot of discipline for now, but what's the pace, or how's the pace of inquiries for new capacity and new projects then, and do you see [Indiscernible] what they're thinking with commodity prices, just trying to drill into existing capacity to take advantage of high prices quickly? Or is there a growing willingness that you're seeing to make a long-term infrastructure commitment?

Robert, you would know that answer as well or almost as well as we do. There's so much excitement in the sector and so much cash, and dividends, and share buybacks, and even when the producers are allocating a ton of money to both of those activities. I looked at -- through some tables the other day and the average net debt in -- at the end of 2022 for the Canadian junior intermediate sector and the U.S. sector is actually negative. On average, people across the sector are not going to have debt. They're going to have cash in the bank. The only people that are going to have remaining net debt are the seniors in Canada and they're all meets -- meeting their targets, I read Cenovus's release. And so the question remains at these prices, and with the economics of oil and gas well drilling, I mean, the silver lining through the horrible pandemic is man, people learned how to do stuff with low at low cost. And so, the economics of wells -- of activities have never been better. The question to me then is when and there's lots of talk still at a Cop 26 and everything that is a headwind. But most producers don't have any reliance whatsoever on capital markets anymore. They're completely internally funded, they don't need bank debt. They got cash in the bank and my prediction is -- this is one man's prediction, is when they can drill gas, drill oil with very fast payouts and with hedge able commodities that they're going to start to take round. Particularly drill-to-fill situation. So a producer has capacity in their gas plant or we have capacity in our plant or they're paying for service that they're not fully utilizing. As we said…

That's good color. If I can just turn to marketing and a couple of questions here. You had a statement that you expect marketing to be above average in 2022, and I'm just wondering, I guess, with the changes in your business and the like, and over what time period, what are you seeing as average? The second part, last quarter on the hedging program, you disclose that pricing on the hedges you added for '22 were in the range or getting a little above the prevailing spot frac spreads in the first half of the year. I'm just wondering if you can give an update on pricing for the hedges you've added subsequent to the quarter.

Scott, you want to -- that's always a delicate question, maybe, Scott, you could take that one.

Yeah, Rob. We added the 25% hedges throughout Q2, so those would have been at roughly prevailing prices as it relates to Q2. Obviously, since Q2 we've seen a continued increase in rally in the prices. Those 25% that we initially put it in Q2 would be slightly out of the money today, nothing material I'd say 15 -- call it $15 million roughly out of the money, and then the 12% that we added was within the past several weeks here. So relatively close to where the spot pricing is for 2022.

Got it. And then just on the overall above average commentary on marketing? How are you calculating what's average for you?

I will give you a course answer like 2020 was like a P10 year. So on any given 10-year stretch, in the bottom 10% this year given the strong second half in the way the year -- towards a year-end look, we'll be a P, like an average year. And next year will be a very good year. So I would say, you never know, Robert, like forward-looking information but it could be a P75 year or -- or better, but we'll wait to see. Remember it's not just one commodity, it's differential pricing that really is key in how we make money and it's really difficult to predict one commodity versus another, but if things were to -- not to change from today's pricing, we have a very good year.

Robert, I would just also add that obviously depend early December we'll be putting out our capital budget and our 2022 guidance. And at that time, I think we'll be able to provide you a little more color to help you with that answer.

Fair enough and maybe just a follow on that, I know that's it's partly marketing, partly maybe facilities, but just any commentary as to what track tightness, NGL kind of mix sloppiness, given the planes outage and what that means, both near-term and end of '22.

Jaret, do you want to talk about where we sit? How big you think Redwater and the general Edmonton Frac Complex is and maybe that can help Robert out?

Yeah Robert, Good morning. Yeah the Frac Complex, obviously it did get back a couple a little bit with some of the challenges that happen there in the late September. But overall, even on a run-rate basis, the Frac Complexes in Fort Saskatchewan, they are highly utilized right now. Everyone, including ourselves, we're seeing stronger physical gas volumes. Some of our customers have shifted. Their portfolio is a little bit maybe not as heavily condensate weighted, and a little bit more into that -- very liquids-rich, but still a lot of gas coming there, which is driving a lot of NGL 's down through the value chain. and they are all showing up in Fort Saskatchewan, so highly utilized thankfully, everything's rocking and rolling with the assets and we're seeing a lot of high-processing rates. It's going well and it's looking really good for -- when you talked about -- or there maybe there was a question earlier about where the customer's asking for incremental services. There are certain segments of the entire value chain where there are bottlenecks, and that would be one where obviously Pembina looking at RFS 3 going to the [Indiscernible] there and going to the full C2 plus like Redwater, RFS2, etc. Those are -- those are the types of things we're looking at right now to help accommodate the customers increasing NGL s.

That's great. Thank you.

Go to our next question from Andrew Kuske with Credit Suisse.

Thank you. Good morning. I guess this question is for Mick and it's really when you look at your footprint that you've got and you think about green hydrocarbons attracting premium pricing to what extent do you start allocating capital to effectively provide your customers a turnkey service on a value chain basis for capturing carbon, moving carbon, and then eventually shipping out green hydrocarbons at premium prices, how do you think that fits into the Pembina Store that you've got?

Well, I think you're seeing real examples here, I mean, the Cedar LNG Project, for example, is using green power. And so it will probably be the greenest LNG in the world. I can't imagine how it would be better than that. So that's obviously is going to be a coveted product. We are not participating in the generation of renewable power, but we're acquiring renewable power from long-term renewable power. We've announced the deal. We see the prospects for doing more of that to help drop our emissions intensity and if possible, our overall emissions. Particularly if we don't keep growing. So that's well underway. We are looking at on a micro -- on a pilot basis sequestering all the carbon at Redwater. That's our largest single point emission source. And we have suitable geology and we can be customers of the Alberta Carbon Grid an existing pipe there ourselves, we're looking at similar kind of micro sequestration opportunities in some of our larger point emission sources in the field where we have the combination of the right geology and where we're using gas. You turn to Garrison Midstream. Most people don't know this, but that's all hydroelectric power there too. We've got a BCF a day of gross capacity there that's all run on green power, so we're well down that road. And so, we compare pretty well on the benchmark basis and we're going to take -- keep taking ground and then, we're trying to -- those are the things that we're doing to put Pembina on right footing and in the right direction. But we're not stopping there. We're actually trying to provide an industry solution, as you described. Now, the -- one of the most important things, though, for the industry solution is that we and our partner TransCanada is the largest pipeline owners in the province. So we've got most of our pipe in the province as does TransCanada in terms of NGTL, both open access service providers that we're going to combine. And we have combined our efforts to provide a grid, an open access grid, like Pembina does in oil and NGL and TransCanada does on NGTL, and use our surplus pipe and our -- as Stu said, our capability. But we need the poor spaces, sequestration rights, to be able to offer those services to customers. We look forward to doing that. We aspire to do that but obviously, where you put that stuff is really important to that equation but we'd love to have that in the Pembina store, and we're going to be users of that store ourselves.

That's very helpful color and context, and I guess maybe just a follow-on and it relates to -- on the sequestration side of it. Do you think the pricing regime in Canada is enough -- the pricing regime on carbon is enough to really stimulate capital, or do you need 45Q equivalent in Canada to really drive more capital into that -- into that industry?

Jaret, do you want to take a crack at that, and I'll add my thoughts after?

One moment while we -- one minute. And it looks like we have lost them for just a moment.

Okay. I'll take that. I think it -- I think the carbon grid and the sequestration transportation can work at today's carbon pricing. I think the capture -- the capture is the most capital intensive part and that's where the levels of government need to kick in is really to help producers, the emitters, capture their emitters. It's all well understood technology. It's technology Pembina knows and has experience with. But it's capital intensive and so we do need assistance from the government with investment tax credits or faster rate off tax pools, or just REIT incentives to get that started and then we will be good. I think the projected carbon tax in Canada is way beyond w hat we see in the U.S. and I think almost anywhere in the world and -- clearly we're about to come to pass. Carbon capture could be economic.

Okay. That's very helpful. Thank you.

I'll take our next question from Robert Catellier with CIBC Capital Markets.

Hey, good morning, you've actually answered the majority of my questions, so just a couple of small ones here. I noticed there was discussion in MD&A about using rail transportation to position some Propane [Indiscernible] I'm wondering what you are seeing the fundamentals there to support that decision, and second part is, do you see that as just a tactic based on the current market or is that more of a long-term strategy?

Stu, maybe you and Jerry want to tag team on that.

I'll start and then Jerry can jump in. So Rob, thanks for the question. This is not uncommon for us. We actually have been using our current asset. We've railed the products in. We do like -- we'd like the Sarnia Market. We like the seasonality of the Sarnia Market. We're coming into -- to a valuable time so, yes, the economics do justify the cost to rail our product at this point in time and it's nothing new for us. We've done it on a regular basis, so Jaret?

No, nothing further.

And then just with the third-party outage and the take-or-pay fee relief related to that. Do you have any line of sight as to when that might mitigate new -- get back to normal operations there?

Jaret, maybe you can take the operating part, and Scott, if you want to chime in on any financial things you want to talk about there?

Yeah, Robert, everything is back to 100% operating on our side. And it's been, I don't know, like we'd probably have to get a yes, but it's been a couple of weeks now that everything has been back to normal. Rob, we don't expect any material impact to our Q4 results.

Okay. Thanks, everyone.

We'll take our next question from Matt Taylor with Tudor Pickering Holt.

Hey, good morning everyone, thanks for taking my questions here. I just want to go back to Alliance [Indiscernible] some commentary on how rates on their new contracts compared to the historical rates, just as we saw this spread for ACO to Chicago is quite tight there for allowance for the past quarter or two. So any comments on that and then I know there's been a lot of [Indiscernible] in the market about Alliance and how the 3x oversubscribed open season is changing your outlook for that pipe longer-term.

I'm just going to make one comment and then turn it to Harry. Our longer-term outlook on that site has never changed even when we had $0.60 differential, it's going to move around but our, and I know our partner Enbridge, our view has always been that's the best pipe from Canada going into the U.S. And our outlook's always been very positive about that pipe. Harry.

Thanks, Mick. And good morning, Matt. I'll just follow behind Mick on the longer-term outlook. At mixed rate, the structural advantages that Alliances enjoyed over 20 years, we firmly stand behind them. Stu and Mick of talked about we're seeing some additional structural event and just come into play for Alliance around the LNG exports off the East Coast. And also, in the U.S. Gulf Coast, combined with what we're seeing is still a movement towards switching from coal fire to gas-fired, and nuclear to gas-fired, as well. So, long-term, the structural manages that Alliance enjoyed are still there and would actually seem to get being a bit more robust. From a pricing perspective, I will talk about in terms of the 2021, 2022 gas year. So the volumes that we picked up there were on average about 130% in excess of the current toll. For the 2022, 2023, and longer gas year and beyond that, we're currently in a process with working with the shippers out there. So there's not much I can say, but we're expecting to have an update before the end of the year.

That's great. Thanks for that, Harry and Mick. And then I have one on Cochin as well, probably first need for Scott. Is that deferred revenue issue material and is that just a one-off? And then, previously you guys have been talking about potentially adding more capacity. And Mick, is outlined bullishness on volumes here are conversations heating up there that capacity could be imminent as well? In your capacity, that is.

I'll take this first part of that question and then turn it back to Harry. Matt no, the overall -- the overall result was not material and a lot of it just relates to the timing of makeup rights and other things on our system, so it was less than $10 million to the quarter. With that, maybe I'll pass it over to Harry.

In terms of increasing the capacity of the Kotian, discussions are ongoing and obviously the condensate market in Alberta is very robust and I think we feel positively about the direction alliance is going both, sorry, Kotian is going both from a volume and price perspective.

Great, thanks for that. And then last one for Mick. Can you elaborate a bit more on -- there are some comments are there in the press about you've seen the benefit of combining some of the CCUS projects out there and some of the pushback we've been hearing your lives as of hardy premium for that service. Some of those either continuing projects might be a bit more refined in [Indiscernible]. So would you mind just touching on some of those key rebuttals and what your vision is for a broader system in Albert?

Yeah, It's confusing how someone could say they would need to pay a premium given that our pipes are -- that we're proposing to utilize are fully depreciated and we're only trying to make a return on incremental investment, which we've said to the market, we expect to be about $0.50 on the dollar compared to new, whereas other proponents need to build brand new pipes. I can't really ascertain the root of that comment. But listen, if someone can do it less costly on there own, clearly there are going to do it and I guess we'll wait and see.

Great Thanks for that.

So to our next question from Linda Ezergailis with TD Securities.

Thank you. Recognizing will get more information in December and I look forward to that. I'm wondering if you could help us understand in the meantime a little bit about where there might be some operating leverage that you could benefit from in your system in 2022, volumetrically. Any updates you could provide on key sensitivities, whether it'd be commodity prices, FX, or anything else would be helpful. And then from a [Indiscernible] perspective as well, how might we think of inflation [Indiscernible] versus point on the revenue side versus the cost side in terms of any virtual protections in place and whether that might -- inflation might actually prove to be a net tailwind for you next year?

Yeah, I'll take a couple of those. Starting with inflation, when we think about scarcity of goods and services, the number one thing is we've got to take good care of our employees because a lot of the scarcity we're reading about has to do with employees, and so we're very focused on that. And then the next thing regards to cost is making sure you have all the spare parts you need, is as we're all learning in our personal lives, it's hard to get stuff right now. So we've looked at having critical spares and spare parts in inventory across our systems. In terms of the monetary part of inflation. Number 1, I think about 3/4 of our operating costs are pass-through. We're obviously very cognizant that those cost matter to our customers. And so we're doing everything we can to drive efficiency, and we've literally put tens of millions of dollars of efficiencies into our business since 2020, and that remains an ongoing focus of ourselves and our board. Lastly, we observed that often inflation does correlate relatively well to commodity prices. And so, to the extent we're left with remaining residual inflation, we think there's a good hedge. At least that's what's happening now. I would say our ability to make money from more marketing business is going to far outstrip inflation that we see. On the financing side obviously, inflation can lead to interest rates and we're really well hedged in terms of long-term interest rates. Maybe Scott wants to add something to that. And lastly, you -- or second last, I'll open it up probably to Scott next but where do we have leverage? We have leverage on [Indiscernible] midstream. We have quite a bit of capacity there, we have leverage, obviously on Kotian, we have some very low-cost expansion there. We have a low cost expansion on Alliance that we've talked about in the past, you never know, we have significant leverage across our conventional pipeline business. We are still operating in our business around 3 quarters to 80% full, and so, tremendous torque on adding barrels there. The places were more full, as Jaret said is on our frac business and some of our other gas processing businesses. So Linda, we can run quite a while within our footprint, but -- and that sounds great and it is great, but it also is dependent on where it comes on the system, like we're building Phase IX because the product is coming on at a part of our system way at the end where we don't have quite enough capacity. So sometimes you still have to deploy a bit of capital depending on where that product comes on. I'll open it up to my colleagues here to add some color.

Linda, I would just add about 90% to 91% of our debt is on fixed rate. So we do have somewhere in the neighborhood of $900 million that 's exposed to floating rates that we're looking at what to do with that here in the short-term. We also have short-term rate exposure at Garrison Midstream as well, but we've hedged 50% of that away. And as it relates to sensitivities, you just bear with us one more month we'll obviously have lay out all of our sensitivities in conjunction with our 2022 budgets. So that will form part of that press release.

Thank you. And on a separate note, some headlines recently that your Oregon LNG Pipeline approval was to get a new FERC review, recognizing what's not a high priority initiative now. Just wondering what the thinking is there, and might others in the industry maybe find more value in that initiative or what are the moving parts?

Janet, are you able to speak sense to that?

This is Janet and thanks for the question. I think as we've announced previously, we paused the Jordan Cove development at this point. And while we haven't made any decisions; we're continuing to work with Burke, including on the appeal. So I think we'll have to continue to evaluate. We do see that there is value to this asset in some way, shape, or form so I think more to come on that.

Thank you, and maybe as a broader question with respect to maximizing value, how my acquisitions and divestitures be leveraged where outright trading of assets might optimize bigger lower-cost solutions for Industry versus partnering like resuming with the Alberta Carbon Grid.

Linda we're -- that's a great question. Ultimately, assets audit end up in the hands of the owners who can utilize them the best. So swapping assets is a terrific solution if they're respectively worth more to the other party. And so we're looking at things like that -- we're looking at the ability to cycle capital, maybe a little more than we -- than we used to. And so, anything is possible, and we come into 2022 -- we'll talk more about that again in December, But extremely well positioned generating a ton of cash with a low payout ratio, very low levels of debt, and a machine that has a lot more upside than downside. So we're feeling really robust about what's possible coming into next year.

Thanks for answering my questions.

[Indiscernible] Linda.

And we'll take our next question from Ben Pham with BMO.

All right, thanks. Good morning. Wanted to ask a question on M&A. I'm curious of the activity you're seeing your appetite [Indiscernible] willing sellers out there given improvement in asset values and other geographies that we look to now they haven't slipped before. I mean, I'd love more high-level comments on M&A.

Yeah, sure. We tend to like to grow with connected assets, or assets that are virtually connected through contracts. What I mean by the latter comment is we're not physically connected to Prince Rupert, but we have long-term rail deals that make it, so we consider those still connected and vertically integrated. And the reason we like to grow with connected assets is because as we offer services in the field to customers through the value chain, there's always some part of the value chain that is -- has fair capacity like in my response to Linda, if we got a huge new NGL contract because Dow needed [Indiscernible]. And let's say it's C2+, we built a field facility that would be new capital, but it could flow on our pipe without capital. And so the contribution to our pipe would go right to the bottom line. Maybe we need to build a new [Indiscernible], but we have extra storage, we have surplus rail for this C3+, and we're pipeline connected to [Indiscernible] so no capital there. So you could see in that collage, some activities need new capital and some don't. And the ones that don't add exceptional profitability, some of which we can share with customers, and so we can make nice profits and customers can have better netbacks, and so that's the reason we seek that connectivity. Now if we had a storage terminal in Europe, it's hard to imagine how 1 plus 1 equals 3 there. So we tend to shy away from that and we've also learned that building from a position of strength and -- and assets and -- and customers, we know past question about what's possible downstream the Alliance. Well, we're down in Chicago, we have major assets there so we have familiarity with that business, so that would be a good example of places where we could look, where we have knowledge, and experience, and advantage. And so that's really has and will continue to guide to what we do next.

And then my second last question is on Ruby. The [Indiscernible] track financial contribution, is there a tracking line of your expectations -- initial expectations [Indiscernible]?

I don't -- I'm not sure I understand the question, but I'm going to turn it over to Harry. Maybe he understood and he can answer it.

Yeah. Generally yes, we can't give you the specifics.

There been I think -- obviously, the producer contracts rolled off at the end of July. Q3 was a pretty decent run rate for Ruby going forward. There's been some short-term deals there that have backfilled some of the volumes on a short-term basis, but not meaningful contributors to revenue just given the current spread. But I would say that where we're at, balance of Q3 and into Q4 is going to be the run rate for Ruby.

[Indiscernible]

And that concludes today's question-and-answer session, I'll turn the call back over to Mick for any additional or closing remarks.

Well, thanks, everyone for your questions. We do have to jump to -- we have an Employee Town Hall -- lots of interest, I could tell. We rarely take the full hour, so thanks for your interest. We've got a lot of tailwinds right now. Existing assets are our king, and our customers are healthier than I've ever seen them and the sky's the limit for them. And hopefully, that will turn into volumes as soon and drive our activity forward. Looking forward to providing our updated '21 insights in December and further look into 2022 at the same time. So with that, thank you very much and have a great weekend. Goodbye.

This concludes today's call. Thank you for your participation. You may now disconnect.