Good day everyone. Welcome to the PAA and PAGP fourth quarter and full year 2020 earnings call. Today's conference is being recorded. At this time, I'd like to turn the conference over to Roy Lamoreaux, Vice President, Investor Relations, Communications, and Government Relations. Please go ahead, sir. Thank you, Delora. Good afternoon and welcome to Plains All American's Fourth Quarter and Full Year 2020 Earnings Conference Call. Today's slide presentation, which contains a good deal of supplementary information, is posted on the investor relations news and events section of our website at plainsallamerican.com, where audio replay will also be available following our call today. Later this evening, we plan to post our earnings package to the investor kit section of our IR website, which will include today's transcript and other reference materials. Important disclosures regarding forward-looking statements and non-GAAP financial measures are provided on slide 2 of today's presentation. A condensed consolidated balance sheet for PAGP and other reference materials are located in the appendix. Today's call will be hosted by Willie Chiang, Chairman and Chief Executive Officer, and Al Swanson, Executive Vice President and Chief Financial Officer. Harry Pefanis, President and Chief Commercial Officer, Chris Chandler, Executive Vice President and Chief Operating Officer, Jeremy Goebel, Executive Vice President, Commercial, and Chris Herbold, Senior Vice President and Chief Accounting Officer, along with other members of our senior management team, are available for the Q&A portion of today's call. With that, I will now turn the call over to Willie. Thank you, Roy. Hello everyone, and thank you for joining us. This afternoon we reported fourth quarter and full year 2020 results, each of which were largely in line with our expectations. We also furnished full year guidance for 2021. Al will discuss the results and guidance in more detail during his portion of the call. Let me start off with a few comments on the progress we made in 2020 and our positioning going forward. As we all appreciate, the challenges in 2020 were very significant. I'm thankful for and very proud of our team who demonstrated strength and resilience and worked to overcome obstacles and focused on what we could control. As a result, we accelerated several key initiatives, two which I want to highlight. First, we have fully embraced our company-wide transition to efficiency mode, focusing on streamlining the organization, reducing costs, and working to optimize all aspects of our business. Second, we have positioned ourselves to generate meaningful, positive free cash flow after distributions. We implemented actions that improved our 2020 positioning by roughly $1 billion, and expect to have strong positive free cash flow after distributions in 2021 and beyond. The collective result of these activities allowed us to activate a balanced equity repurchase program that aligns with our priorities of reducing leverage, improving our investment-grade credit metrics, and returning capital to equity holders. Throughout 2020, we had solid execution against the goals we outlined at the beginning of the year, which are summarized on slide four. Notably, we delivered adjusted EBITDA within 1% of our initial pre-COVID guidance, a significant achievement largely accomplished via strong mid-year S&L results buffering the negative impact of reduced volumes on our transportation segment. We completed $450 million of asset sales, electing to defer our process for certain target asset sales into 2021. We also advanced optimization and efficiency initiatives throughout the year, resulting in more than $125 million of OpEx and G&A cost savings, which we expect to endure in 2021 and future years. Most importantly, we continued our progress towards our goal of zero incidents with our best year ever. We exceeded our annual 20% reduction target of our total recordable injury rate and federally reportable releases, resulting in a reduction of more than 50% for each metric over the past three years. In addition to the goals we defined for the year, we continued to increase our alignment with investors and external stakeholders, including many of you. We advanced our sustainability program, improving our disclosures and continuing to enhance our executive compensation program and overall governance framework. With respect to the heightened focus in 2020 on the topics of sustainability or ESG, energy transition and policy agenda shared throughout the U.S. election process, let me share a few comments. Appreciating all of the above, we continue to believe that hydrocarbons will remain a key part of the energy mix needed to meet increasing global population demands and improving quality of life. Mobility, power generation, heating and cooling are all widely recognized as key drivers of energy demand. Perhaps less frequently recognized are the basic building blocks of growth and prosperity, steel, cement, plastic, and fertilizers, each of which require hydrocarbons. We believe the transition to lower carbon intensity will occur over an extended period of time, and that all sources of energy, including hydrocarbons and efficiency and conservation, will be required to meet that demand and to provide a bridge into the future. In that regard, we expect absolute demand for nearly all forms of energy to increase for the foreseeable future and for midstream infrastructure to remain an essential link between energy supply and demand. As a result, we have strong conviction in the long-term value of our business and the sustainability of our cash flow stream. We also acknowledge that we must continuously improve our operating footprint. Building on our safety and environmental performance, reducing emissions, improving efficiency, increasing conservation, and leveraging technology to move whatever aligns with the highest and best use of our asset base and capabilities. As you've likely seen, we've also increased our sustainability disclosures over the past two years, and we plan to issue an updated sustainability report later this year, which will share additional information about our sustainability strategy, progress, and ongoing initiatives. With respect to current industry fundamentals, the unprecedented shock to global demand clearly reset the base for North American production. For perspective, we entered the year expecting U.S. oil production to grow from year-end 2019 to year-end 2020 by roughly 500,000 barrels a day, or 4%. U.S. oil production is now estimated to have decreased during this period of time by 2.3 million barrels a day, or 17%. This equates to a reset of absolute production expectations of more than 2.5 million barrels a day, which has created a significant level of surplus midstream infrastructure capacity for the foreseeable future. As illustrated on slide five, global demand is expected to continue to recover, although the timing of global supply-demand rebalance is subject to multiple variables, including on the demand side, global COVID vaccination pace and effectiveness, and on the supply side, a number of dynamics, including OPEC compliance, natural production declines, continued capital discipline from producers, available surplus capacity, as well as the impact of potential regulatory and carbon transition impacts. Appreciating these variables, we believe that North American crude oil will be needed long-term to support growing global population needs, and that the Permian Basin will be key to meeting those needs. As producers continue to exercise capital discipline and operate well within cash flow, we believe the Permian could grow oil production to 5 million barrels a day within a couple of years, and to 6 million or more barrels a day longer term. Plains has a highly integrated system in place with a significant degree of flexibility, optionality, and operating leverage. Our assets will continue to be critical to meeting the longer-term needs of North American oil production growth while requiring minimal capital investment going forward. The actions we've taken position us to generate meaningful, positive free cash flow after distributions for years to come. In 2021, we expect to generate free cash flow after distributions of roughly $300 million, which expands to more than $1 billion when including proceeds from targeted asset sales. This is illustrated on slide six. I'll also note that consistent with our November commentary on our $500 million common equity repurchase program in 2021, we plan to allocate 75% or more free cash flow after distributions to debt reduction and up to 25% to buybacks. Beyond 2021, as a result of anticipated EBITDA growth and a run rate investment capital of $200 million-$300 million a year, we expect to generate a meaningful level of annual free cash flow. Subject to our annual board review and approval, as leverage decreases over time, we expect the allocation to further shift from debt reduction towards equity holder returns. With that, I'll turn the call over to Al. Thanks, Willie. During my portion of the call, I will review our fourth quarter and full-year results, review our current capitalization, liquidity, and leverage metrics, and provide additional color with respect to our outlook for 2021. As shown on slide seven, fourth quarter fee-based adjusted EBITDA of $555 million was slightly above our expectations. Transportation segment results were in line with our expectations, but decreased compared to third quarter 2020, driven primarily by MVC deficiencies billed and collected in the third quarter related to volume deficiencies from the second and third quarters. Facility segment results exceeded our expectations, primarily due to higher than expected activity and revenues at our Cushing terminal and certain other facilities, and were in line with third quarter 2020, effectively offsetting the impact of asset sales completed late in the year. Fourth quarter Supply and Logistics results of $4 million were below expectations and primarily driven by the impact of warmer seasonal temperatures on our NGL sales activities and less favorable margins on Canadian crude oil activities. Moving to our capitalization and liquidity, a summary of key metrics is provided on slide eight. Our long-term debt to adjusted EBITDA ratio is 3.7 x, which is above our target range of 3x - 3.5 x, and reinforces the rationale for debt reduction to remain a top priority within our capital allocation framework. Additionally, we exited the year with total committed liquidity of $2.2 billion, and we do not expect to access the capital markets for the foreseeable future. Let me share some additional comments on our 2021 guidance, which is summarized on slide nine. Our fee-based adjusted EBITDA guidance of ±$2.1 billion reflects a 2% decrease relative to the preliminary guidance we shared in November and incorporates the anticipated impact of $150 million increase to our 2021 asset sales targets, an additional reduction in our investment capital program, and refined expectations based on our current outlook for 2021. Additional segment-level discussion is provided on this slide, which recaps notable variances to our 2020 results. With respect to our S&L. This highlights our expectation for the continuation of challenging market conditions to limit margin-based opportunities in the future. As Willie noted, we forecast free cash flow after distributions, including targeted asset sales proceeds, to be more than $1 billion, slightly above our November estimate due to the increasing of our 2021 asset sales target by $150 million to a total of $750 million. A top priority continues to be maximizing free cash flow after distributions and allocating capital in a balanced and disciplined manner with the intent to reduce debt and prudently return cash to equity holders over time. We remain focused on disciplined capital management and with the prerequisite of high return must do, no regrets for every incremental dollar invested. In that regard, as shown on slide 10, we exited 2020 with investment capital $30 million below our November estimate, maintenance capital $35 million below our February estimate, and we have further reduced our 2021 investment capital guidance by 15%, from $500 million to $425 million. I'll note that a high-level overview and status update for our two key projects that remain underway is provided on slides 26 and 27 of the appendix of today's slide presentation. With respect to returning capital to shareholders, thus far, we have repurchased 6.6 million PAA common units for $53 million with an average price of $8.12 per unit. Consistent with what we have previously communicated, we plan on allocating 75% or more of our 2021 free cash flow after distributions to debt reduction, with the remaining balance available for equity repurchases. In the event of meaningful asset sales like we are forecasting this year, we may allocate a higher relative percentage towards debt reduction in recognition of the EBITDA loss associated with the asset sold. To be clear, we do not plan to utilize debt to fund equity repurchases. With that, I'll turn the call back over to Willie. Thank you, Al. Our goals for 2021 are outlined on slide 11. We remain very focused on the long-term positioning of our business, which is built upon our continuous diligence of operating safely, reliably, and responsibly, generating meaningful multi-year free cash flow after distributions, strengthening our balance sheet and financial flexibility while prudently returning cash to equity holders, and continuing to advance our sustainability program and disclosures. We believe hydrocarbons will remain a key part of the energy equation going forward, and we believe in the innovation of our industry, our PAA team, and the flexibility of our assets to meet the evolving energy landscape. Energy infrastructure is and will remain the critical link between energy supply and demand, and we believe in the long-term sustainability of our assets, operations, and cash flow. Thank you for your interest and support of Plains. We look forward to providing you with more additional updates on our continued progress. With that, I'll turn the call over to Roy, who will lead us into Q&A. Thanks, Willie. I'd mention that a recap of today's call is located on slide 12. As we enter the Q&A session, please limit yourself to one question and one follow-up question, and then return to the queue if you have additional follow-ups. This will allow us to address the top questions from as many participants as practical in our available time this evening. Additionally, our investor relations team plans to be available throughout the week to address additional questions. We are now ready to open the call to questions. We'll move first to Jeremy Tonet with JPMorgan. Hi, good afternoon. Hi, Jeremy. Just wanted to dig in a little bit more, if I could, on the key-based guidance for 2021 coming down a little bit here. Appreciate a portion of it probably is coming from a bit more asset sales, but still seems like that's not the full bridge there. If I think about when you guys gave guidance last quarter, if anything, the environment has probably somewhat improved with WTI moving up the way that it has and maybe at the margin, producers expecting a little bit more production. Granted, that wouldn't materialize till later in the year, but I guess we were just thinking there could be more upward bias than downward bias to the guidance here. Just wondering if there's any other moving pieces we should be thinking about. Al, why don't you take that? Yeah. I'll take a shot at that, Jeremy. Asset sales are clearly a part of it, as well as our CapEx reduction and some of the optimization around the CapEx program coming down. As well as just differentials out of the Permian make movements both north to Cushing and to the water more challenging. We've dialed that into our thinking as well as just activity through some of our facilities and utilization of some of our facilities on the crude and NGL side. Jeremy, this is Jeremy Goebel. One thing to add, there's a significant component there is, as Al mentioned, optimization of CapEx. We've worked on eliminating additional capital by de-scoping projects, and that's a significant component on the pipeline side, but that's really deferred revenue and not lost revenue opportunity. We've worked on those components. That's the biggest driver in the capital reduction and also revenue. From a net free cash flow basis, you're neutral to positive, and longer term, we haven't lost the revenue-generating opportunity. Jeremy, one more thing that I'll ask Jeremy Goebel to comment on. Our premise for the Permian, really, even though in the higher price environment, our belief is that there's going to be more discipline from the producers in bringing free cash back to their shareholders or taking debt down. Our forecast is really a modest growth of production, flat to modest growth in the Permian. Probably not to the extent of what the flat price infers based on history. That's great. This is Jeremy again. For 2021, our view, and Jeremy usually asks this question second, so I'm just going to preemptively answer it, is modest growth of 100,000, 200,000 bbl a day this year. Larger public companies sticking to 60%-75% of recycle ratio, reinvestment. That's trended down as prices have run up. We really haven't seen the material increases in rates to drive additional production growth. This will ultimately lead to the upstream companies being in a much healthier position going into 2022 if prices stay where they are. It likely leads to more moderated growth than pre-pandemic levels, but it could lead to more ratable growth and more predictable growth. Everyone on the production side is being cautious with respect to adding incremental production until demand returns, and then the OPEC barrels come back to market. Once you see those two things happen, I think you'll see a more constructive environment for activity, and you'll have healthier balance sheets. The smaller E&Ps and some of the under-levered private guys are getting out in front of this, but not enough to make a material impact to 2021. This is largely around the Permian. The rest of the basins we have largely flat to slightly declining, even with the higher flat prices. While that may mean conservative, if you think about any rig additions now are impacting six to nine months out of production. Anything that's happening in this front period is really impacting the second half or the latter part of the year. Very constructive going into 2022, but we're, for obvious reasons, being cautious until demand and OPEC barrels get back to market to more moderated levels. Got it. That's a helpful color. Thank you for that. Maybe kind of just shifting gears a bit here with the move in propane as we've seen it. We were thinking there could be more kind of upside bias to S&L here, but didn't look like there was much showed up this quarter. Not to be executive, but even in the first quarter, it doesn't look like necessarily it's making a big impact there. Just wanted to get to the core of the NGL business, and is that something that you guys still think of as a core business, or is that something that maybe someone else could derive more value from just as you think about coring up your business, paying down debt, and increasing returns to shareholders over time? Jeremy? Jeremy, this is Jeremy again. Warmer weather persisted through the fourth quarter and even January. It's not just until the last couple of weeks to where you saw the markets we sell into are largely the Midwest and the Northeast. As those inventories drop, basis improves. We'll capture more opportunities. Some of that could be pushing into later in the year as the cold has just started. The more persistent this is, the cold weather, the more likely you'll see draws to more normalized propane in those regions. It could just push the opportunity out until later in the year. We're certainly paying attention to it. It is a core business. It's a large business for us, and we're going to continue to optimize around it. Yes, there were some large backwardation, but that was largely driven by Gulf Coast pulls and not necessarily pulls in the Northeast. Hey, yeah, this is Harry. I'd also add, what you saw last year, especially with the inventories in Canada, was when you got into that market in sort of the spring of last year, April, May, even into early summer, June, decreased demand, inventories swelled in Canada. We actually ended the year with higher than normal inventories in Canada. That also impacts the margins to generate out of that business. We have seen a run-up in NGL prices into this year. Also keep in mind, we treat it a little bit like a manufacturing business, and we do hedge. We don't sit there and just take spot prices all day long. You have to factor that into your thinking, too. Just because near-term prices pop doesn't mean that we're exposed. Likewise, if they decline, we typically have protection against it. Got it. I'll stop there. Thank you very much. Thanks, Jeremy. Next, we'll move to Shneur Gershuni with UBS. Hi, good afternoon, everyone. Just wondering if we can revisit the guidance responses to Jeremy's questions. The explanation, if I understand, if you can sort of square this for me a little bit, is partially due to asset sales. You also said that there's going to be less capital and mentioned optimization as part of it. The CapEx is only down about $80 million if I read it correctly in your slides. I was wondering if you can expand on it a little bit. Are you saying that you're more conservative than you were in November? I'm just trying to understand if you can get into a little bit more detail about what's changed. Secondly, given the S&L is going to be a lot lower than last year, is there going to be a working capital release that comes with that? Yeah, Shneur, this is Willie. Let me start, and others can jump in. One of the things I want to make sure people realize, when we talk about where we're embracing efficiency mode maximum cash flow, that is exactly what we're doing. We're trying to figure out how do we maximize cash flow in everything we do. The one example that Jeremy Goebel gave was as we think about CapEx and commitments on volumes to it, if we were able to save some CapEx on a piece of work and not spend it in exchange for an NPV neutral, pushing some cash flow out. It's things like that that are driving the reduced CapEx, and it's frankly a better resolution on talking with producers and getting our arms around what we expect to happen. Anyone else want to add to that? I guess the second part of your question was around working capital release with less S&L. This is Jeremy Goebel. I think that will happen throughout the year. As the markets moved into backwardation, at some point, we will opportunistically take positions off, and that would allow for a release of the short-term debt or working capital. We're being opportunistic around it. Okay, great. As a follow-up question, in your appendix in today's slides, you've got an investor FAQ. You specifically address federal lands. I was just wondering if you can expand on the federal lands exposure. I think during the last call, you had said it was about 20%, but it's not listed in the slide here. I was wondering if you can sort of talk to what you think your exposure is if the current drilling pause or permit pause lasts for more than a couple of years. Jeremy, you want to take that? Yeah. Shneur, this is Jeremy Goebel. I would say, one, we're in a wait-and-see mode. I think from a producer standpoint, consistent with other commentary and other calls, is the expectation is that producers at some point will be able to develop the leases that they have. No-new leases seems like a probable opportunity. We need clarity on the land and right of way on multiple fronts. Will it potentially take longer times to get permits? That's definitely possible, but I don't think people have given up on New Mexico at this point. I think there's a lot of opportunity around it. Will that impact us? Sure, it would reduce capital as well as potential impact on production, but still that 15%-20% number from a total dedication. A lot of the producers that we have in New Mexico also have inventory in Texas that's very much with higher gas prices and higher crude prices as well in the money. I don't know that it's an absolute loss, and if we don't get it in New Mexico, we don't get it at all. I'd say there's probably a pivot to more state land in Texas, and a lot of the same producers we have in New Mexico have significant inventory that would be well in the money on the Texas side. I don't think you can just say Plains is going to lose 15%-20%. You have to look at the whole picture. I'd say what's lost in New Mexico is not a total loss to Plains, is one way to look at it. Got it. Thank you very much, guys. Really appreciate the comments. Stay safe. Thanks, Shneur. We'll move to Michael Blum with Wells Fargo. Thanks. Good evening, everybody. I guess first question I wanted to ask was around the decision to continue to allocate some of the excess cash flow to buybacks. I guess just given the reduction in EBITDA guidance and perhaps some of the pressure that'll put on the balance sheet, why not just use all your free cash flow to reduce leverage this year and wait for a bit of a rebound? I'll make a comment, then Al, I think, can jump in and add to it. One of the big things that I'm glad you brought up free cash flow because that's clearly when we think about EBITDA, it only translates into free cash flow. When you think about the asset sales that we've got this year, Michael, it's a pretty significant chunk of capital allocation, which we think we can really take that balanced approach to both the equity holders and continue to reduce debt. Al? Yeah. Michael, as we mentioned in the commentary, our primary focus will be to debt reduction, 75% or more. Again, with the vast majority of what we expect in our guidance of coming from asset sales, we're going to recognize that we're probably going to have to allocate more against debt reduction in this year. We're very much focused on that, but we also want to be able to support our equity as well. Again, leverage valuation of our shares as we go throughout the year, outlook of the business, what oil prices are doing, what producer activities are, all those will get dialed in. There is no just prescribed formula or approach. We're going to try to balance all of that. Again, just to be clear, our focus will be to reduce debt and make sure we manage our leverage. We also want to support our equity. Great. I appreciate that. My second question is just on the increase in the asset sale target. I'm sure you don't want to tell anyone here what assets you're considering, but should we assume that you have now contemplated selling additional assets, and it's not that you think you're going to get better pricing on the existing asset sales you were targeting? I would tell you, Michael, it's increased confidence in being able to execute what we had considered, and I'd leave it at that at this point. Great. Thank you very much. Thank you, Michael. The next one. Move to Keith Stanley with Wolfe Research. Hi, thanks. First wanted to follow up on the last question on the asset sales. Can you just give more color on, I guess, the amount of progress you've made to date, where you are in the process? It's a big dollar target. Should we think you're in active discussions now? Is it still mainly identified assets, and thoughts on timing for executing that throughout the year? Jeremy? Yeah. Thanks. This is Jeremy. I'd say year-to-date, we've closed $20 million in asset sales, which those assets generated close to $2 million annually of EBITDA. The rest are in various stages, whether it's in bid rounds, kicking off the process. All sale processes are underway. That should give you a sense for timing. There's nothing that we haven't began marketing yet. This is all things that are actively in the market and in discussions with other parties. Okay, great. Follow-up question, a separate one. Can you just give an update on where you are in the permitting process for the Diamond expansion project? Are there any key permits you still need for that one? Not sure if you've broken ground yet. Just an update on the process and timeline. Thanks. Keith, I'll let Chris Chandler handle that one. Keith, this is Chris Chandler. We've secured all of the environmental permits that we need for the Diamond expansion project, and those are federal, state, and local permits. Everything that's needed to begin construction there. All long-lead equipment and pipe's been ordered. We've secured 95% of the right of way. We're targeting to begin construction in the second quarter of this year, and still are targeting to have the line in service by the end of the year. I will note that we're taking some time to continue our engagement in the community. We've met with elected officials, we've met with local businesses and community leaders all along the route, and ultimately, we're looking forward to safely and responsibly building and operating a pipeline that'll be a long-term benefit to the region. Thank you. Next, move on to Colton Bean with Tudor, Pickering, Holt & Co. Hi, Colton. Hi, how are you? Just to follow up on the discussion around Q1 EBITDA guidance, looks like it's just shy of $500 million. Can you frame to what degree the step-down is driven by the fee-based business versus essentially a negative result in S&L? I guess as a follow on, Q1 traditionally a seasonally stronger quarter due to NGL marketing margins. What factors should we be watching to drive that ramp back to hit the full-year guide in later quarters? Al? Yeah, I'll take a shot at it. A large piece of it is related to the fee-based. We aren't necessarily assuming a strong S&L quarter as well. There's a number of things that add up. The differentials in the market for moving barrels out of the Permian, whether it's to Cushing or to the water. We've modeled some impacts relative to refinery turnarounds. Again, on our gathering systems, we have some producer forecasts that have been revised down for first quarter. Not necessarily an impact for the whole year. Some of the terminals, some of the utilization and throughput where we've seen positive impacts this year, we're not necessarily forecasting that those continue. MVC timing on pipes have a bit of it as well, as well as just some natural timing on operating expenses. No one particular item, but the large piece of it is a result of the two fee-based segments. Got it. Just to follow up on Jeremy's comments around producers potentially reallocating from New Mexico to Texas if federal permits aren't forthcoming. Is there a material variance in infrastructure positioning between the two regions of the basin? Thinking in terms of potential CapEx impacts if producers were to shift their longer-term allocation plans. This is Jeremy. Realistically, in New Mexico, we do more of the wellhead gathering. In Texas, a lot of our position is around central gathering. On the Midland side, there's some wellhead connects, but for the vast majority of our Texas position, it's behind existing batteries and positions. It could yield lower CapEx outlays in Texas, but all in all, tariffs are somewhat similar between the two regions. Thanks. Appreciate the time. Thanks, Colton. Next, we'll move to Jean Ann Salisbury with Bernstein. Hi. Your segment EBITDA for facilities next year is guided to $0.42 per barrel, which is lower than it's been in a few years. I see on slide nine that you talk about the lower utilization at the NGL and crude storage facilities. Could you talk a little bit more about what's driving that and if it's structurally going to be lower? Jean Ann, this is Jeremy Goebel. Part of this is driven by market structure. If you look at the steep contango and steep backwardation in the NGL side and the crude side, it's just less opportunity to store. I think part of that is driven there. From a structural standpoint, as you get to seasonal norms in NGL's summer-winter spreads, you can see some of that come back, but ultimately, we're just looking at the current market structure and making an assessment. Right now you're in pretty steep backwardation. What happens is some of the facilities aren't as fully utilized because of backwardation. Got it. It could be- Yeah. ...anyone. It could be your storage. Yeah. The other point, this is Al, that I would throw on, you mentioned the per unit. Some of the asset sales have impacted the business mix there as well, like the L.A. terminals as an example, that we divested here in 2020 in the fourth quarter. Some of what we anticipate change that business mix a little bit on a per unit basis. Got it. Okay. Just to follow up on that, I thought that most of your crude storage was, as you call it, operational, and didn't move too much between contango and backwardation. Is this just kind of on the margin, what does move, even though most of it is operational? Jean Ann, this is Jeremy. On the NGL side, it's more exposure to the seasonal spread. There's lower contracted on the crude side for our large facilities that largely contracted. There is some operational storage. We can contract opportunistically when you're in steep contango like last year, so we can flex and make more available. Last year with steep contango, we were able to flex into more. The large facilities that are contracted, that business mix hasn't changed. It was more opportunistic on the crude side from last year. On the NGL side, the seasonal spreads just aren't there right now. Got it. That's really helpful. Just as a quick follow-up, if DAPL does end up having to shut down, what's the availability of your Bakken rail terminals to start loading ASAP? Jean Ann, this is Jeremy again. I would view that as a secondary impact relative to the other exposures we have, right? You could look at our Wascana and Bakken North assets that could move barrels out of the Williston. You look at our capacity from Guernsey South that connects into the pipelines to Cushing from Platteville. Those would be substantially larger impacts, that's readily available now. We will be able to rail too. Yeah, you will, but I think the impact would be substantially larger on the pipeline side. Jean Ann, this is Willie. One comment I would make is, clearly what we all seek is regulatory certainty when you have permits. We're watching this very carefully. As Jeremy talked about, we do have a flexible system, and as we have in all of our regions, if there are disruptions, we should be able to adapt and adjust to be able to, one, get barrels to market and capture some value there. Got it. I couldn't agree more. Thank you very much. That's helpful. Thanks, Jean Ann. We'll move next to Michael Lapides with Goldman Sachs. Hey, guys. Thank you for taking my question. I hate to beat the dead horse here on guidance, but I'm going to try to be pretty specific. I don't know if you all can. How much higher would the EBITDA guidance have been if you weren't forecasting the $750 million of asset sales? How much do those asset sales, the ones you've now completed, impact what guidance would have been? I'm not sure we can comment on that, Michael. You could apply just a round number multiple to it to get an order of magnitude. I don't think we're ready to disclose that. But you think somewhere between the- Michael, I- If I use somewhere in the $710 million directionally, I'm not going to be terribly far off. Michael, this is Jeremy. I just don't want to disclose anything that could impact valuation of the current processes. Please understand, those are confidential, and we don't want to guide in any way on the asset sales and the potential impact. I hope you can appreciate that. Michael, this may help a little bit as well. Everything we've been talking about as far as guidance, in November, we were $50 million higher on what we thought our preliminary guidance for the fee base was. Where we sit today with the disclosure that we've shared on slightly up, I would tell you that it's a fairly measured approach. When I think about where we are right now, sometimes you read the headlines, and it seems like everything is fixed. There remains a lot of uncertainty going forward. The measured approach to where we think things are going, I think, is actually prudent. Anything that we look at, a lot of it's going to happen later in the year, as Jeremy Goebel mentioned. I just want to make sure I qualify that as people think about where we are on how we're thinking about the year. It is a measured approach with certainly less impact in the first part of the year. If there is upside, it's probably going to be in the back half of the year. Hopefully, that helps. No, super helpful. One follow-up. I'm just curious, how are you guys thinking about the Canada business and how it fits in strategically to the broader portfolio? Jeremy? Thanks. This is Jeremy. The Canadian business, we've spent the better part of the last year integrating that system from an executive side all the way through to operations, and we continue to see more opportunities to optimize around that business and further integrate into the U.S. business. I think we're really excited about those opportunities and view that as a core asset in the business that we've been working around to better understand and more commercially align with how we operate and manage risks here in the United States. I think that integration process is underway, and we look forward to continuing to work with, as a group, to get there. Got it. Thank you, guys. Much appreciated. Thank you, Michael. Next, we'll move to Ujjwal Pradhan with Bank of America. Good evening, everyone. Thanks for taking my question. Appreciate the color so far on guidance. Wanted to go back on some of the comments you made around the CapEx coming from rationalization while keeping the cash flow NPV neutral. Are you able to comment where you made the CapEx reductions in that particular regard, and whether this could limit operating leverage if we see stronger recovery and growth than you are anticipating? Yeah, Ujjwal, this is Willie. We don't want to share the specifics of any one contract, but you did bring up operating leverage. I will tell you, again, as you go into this, our mission was to stay ahead of the production side. When you think about our system, I know I've shared this before with folks, in the Permian, we had roughly 5 million tariff barrels or barrel capacity, two in gathering, two in intrabasin, and one in long haul. We've built that out over the last number of years. When you think about operating leverage that we have in the Permian specifically, there's a significant amount of operating leverage that we do have that we'd be able to take advantage of. We're kind of in efficiency mode now. We're trying to consolidate, save power, drag reducing agent balancing, all those kinds of things. If there are barrels that need to be moved, that's one of the reasons we've made the strong statement about we have a very flexible system with a lot of optionality that gives us the opportunity to work with either shippers, partners, to be able to optimize. Ujjwal. This is Jeremy. Just to put a bow on that, I think what you're hearing Willie say is that the reduced capital doesn't impact our capacity in any way. We're able to use the flexibility and commercial structure of our business to get to the same result for our customers without spending the capital. This is pure optimization. Got it. Thanks for that. A follow-up on the federal lands issue. Could you share any comments based on your conversations with producer customers on this issue, if you had them? Had they already started thinking about adjusting their activity given the evolving opposition to federal lands drilling here? Ujjwal, this is Jeremy. What I would tell you is everyone's waiting to understand the rules of engagement. It's premature to discuss that. I think the discussions with the producers, largely, you have to look at it, a connection that's going to be made in November. We've already been working that and have right of way. I think very little impact to this year's plan. Is it likely that some of the locations end up drilling permits behind existing pads of existing right of way? Yeah, I think you'll see some of that. By and large, the discussions, somewhat everyone's going to wait and see what the rules of engagement before things that are impact. A lot of the impacts now are things that are impacting the fourth quarter of this year or next year. I think while everybody wants to know the answer today, I don't think anyone knows the complete rules, and once they do, then we'll report back on what that impact looks like. I think we're still in that transition. We've got people just getting into appointed positions, and there's a lot of discussion on the producer side that calls on their positions with permitting backlogs. I think I would just leave it at that at this point. Frankly, it's another reason why we have our measured approach as we think about our fee-based numbers for 2021. Got it. Thank you both. Thanks. We'll move next to Gabe Moreen with Mizuho. Hey, good afternoon, guys. Two quick ones. Can you just remind me to what extent the Capline reversal economics and contractual backing is contingent at all or not at all on the Line 3 expansion coming into service? Jeremy? Gabe, this is Jeremy. It is not contingent upon the Line 3 expansion. Great. Thanks. Maybe just a question on ESG, since it sounds like you're putting out a report later this year. To what extent are you or are you not maybe evaluating some, I would assume, smaller investments like renewables to potentially power some of your pipelines and things like that? I'm just curious if that's something that's on Plains' agenda at the moment. Yeah, Gabe, this is Willie. Maybe Chris Chandler can chime in on some of the specifics. We are looking at a lot of different things around ESG and sustainability, right? I always talk about. First and foremost, you got to run a reliable business. I really laud our organization for making the continuous improvements on safety and on the environmental release side. As far as being able to move different products, that's going to be a longer decision process or development process. When we think about buying renewable power, that's certainly a piece of it, but the economics have to work for us. Chris? Yeah, this is Chris Chandler. I'll just note that we've evaluated a number of opportunities to purchase renewable power under long-term contracts or help underwrite or support facilities behind our meters, like solar, wind, and battery. To date, they haven't met our investment thresholds, I will say they are getting more competitive as time goes on. There's a potential to make some of those investments out in the future. The other thing I'll note that efficiency goes along perfectly with the goals of reducing emissions and having a lower carbon footprint. We are always working on efficiency for that reason and for the cost benefits of doing that. Whether that's reducing the number of generators we use and hooking up to permanent utility power, optimizing our pipelines with drag-reducing agent, or how many pump stations we operate, or the use of variable frequency drives, or what pressure we operate at, or whether we operate at full flow for 10 hours or half flow for 20 hours. We're doing all those things all the time, and those have all contributed to a portion of the cost reduction we've been able to achieve. We're looking at that each and every day. Gabe, I think you'll see more about this in our report that we'll put out later this year on kind of our strategy. It's really putting our arms around Scope 1, Scope 2 emissions, trying to quantify that and also you have to have good data before you can make commitments. We're definitely committed to working through that process, and I would ask you to be patient with us until we share later this year. Excellent. Thank you, Gabe. We'll move next to Spiro Dounis with Credit Suisse. Hey. Afternoon, guys. Hope you're well. Willie, you mentioned optimizing assets. Late last year, you did an asset swap of sorts, and that was fairly well-received. I'm curious how you're thinking about that opportunity set to do similar transactions this year, and are there any specific assets that you've identified, I guess yet, that could make sense to do something similar? We've got a lot identified that we won't share publicly yet, because we're working on it. I can assure you that I talked about it quite a bit because that really is the mode that we've got to get into, is its rationalization. In my prepared comments, I talked about that reset. There's a lot of spare capacity in there. We are continuing to work with potential partners on how do you develop something where you can get a little rationalization and get more capital efficiency in there. More to come on that. I just can't give you a timeframe. Totally. Follow-up to some of the comments made earlier around marrying some of what you said around the 1Q guidance and then Jeremy's comments about ending the year kind of strong and setting up for a good 2022. I guess if you look at the 1Q guidance, it talks about a 23% sort of full-year weighting. You guys have also said that sales are going to be back half weighted. I guess the simple way I thought about it was I would have thought the first part of the year would have been maybe a higher percentage of EBITDA because asset sales were hidden. As you mentioned that the setup here on volume seems to be setting up for a stronger 2022. Are you guys contemplating a strong end of the year, and is there an exit rate on volumes that you could share? The only number I'll share with you is we did talk about the Permian. It's possibly 100 to 200 higher than the beginning, Jeremy, depending on a lot of different things. That's really a key driver, of course, the Permian volumes that we might see. Also as we talked about the higher inventories in Canada on the NGL side, you're going to have more sales weighted. The profile of sales for the NGL business will be different this year than historically. We enter the year with more inventory. There's higher inventories now. We have more inventories to sell. The cold weather's just occurring now. It may push some of the sales into the latter part of the year. I think a lot of this is just sculpting of the NGL sales out of fourth quarter of last year, first quarter of this year into subsequent periods. Appreciate it, guys. Thank you. The only thing I would add to that, too, is we are assuming that our Transportation Segment, while the Permian is growing, it is growing, it is not growing as much as it did in prior years. We do expect to see the Transportation Segment have quarter-over-quarter kind of growth this year. Most of our asset sales are anticipated in our Facility Segment. One last thing, this is Jeremy, is the Wink to Webster project starts in the latter part of the year as well. When that starts contributing, while the pipeline has started up, you have some interim service now, but the real commitments don't start until the latter part of the year. Got it. Thanks again, guys. Be well. Thank you. We'll move next to Tristan Richardson with Truist Securities. Hi, good evening, guys. Thanks for squeezing me in. I appreciate all the comments and helping us understand the guide. I guess I'm just thinking about the price signal that producers are seeing today. You mentioned your customers are reticent to change plans, can you talk about what you're hearing from customers around what conditions we would need to see for producers to come out of maintenance mode? Yeah. This is Jeremy. I think I tried to articulate it earlier. I think to some respect, the current prices are propped up by available production that's off the market by OPEC in meaningful numbers. The struggle is if the U.S. producer base goes and adds a bunch of rigs and commits to a bunch of additional production, and whether demand is delayed, demand recovery is delayed, or OPEC pushes barrels back on, that could change the balance again. I think part of this is waiting for demand to recover, which could be I think we showed some slides earlier in here that shows forecasts, which it ramps between now and the end of 2022, with roughly half of it returning this year. It's going to be, how does OPEC bring production back online? I think people don't want to get out in front of that. Candidly, for them to heal their balance sheets during this period is not a bad thing. There may be more activity. Go ahead. No, thank you. I guess the follow-up, a lot of questions on asset sales, maybe just at the risk of one more. Can you talk about the identification process of asset sales? I think we really think of 2017 and 2018 as the time period where you tackled some really large low-hanging fruit. Can you talk about the most important criteria in the identification process today? Sure. This is Jeremy again. I think the way you look at it is our business works really well when our pipeline facilities and marketing groups all work together on an integrated platform. Things that don't fit within that context are usually things that whether we're strong in one or the other, but we really don't have a market-leading type presence. Things there, or our cash flows that are more difficult to manage, or they have operating risk or high-maintenance capital, things like that have different risk profiles. Let's say all of those are things that are candidates for sale. You see a lot of the smaller NGL facilities around the U.S. we've been selling as we moved out of that downstream-type market. That's a strategic exit from those. You've seen packets to those sales. I think the important thing is from an investment community, a lot of the things you really don't know that we own or operate, we're exiting some of those positions. Some you've seen, like BridgeTex, that we have. A lot of the assets you probably couldn't name. It's just those things where it's not something where our three business segments all are aligned on optimizing value and being in a leading position. Well, historically, we've also sold interest in assets where the counterparty has brought value, so that when you look at an NPV basis, it is actually an NPV accretive to us to sell down a portion of our interest and partner with a counterparty that, like I said, adds value to the asset. I appreciate it, Jeremy, Harry. Thank you, guys. Thanks. That does conclude our question and answer session. At this time, I'll turn the conference back over to our speakers for any final or additional comments. Thanks. This is Willie. I just wanted to make a couple comments here at the end. We've got a lot of great questions from folks, and I just want to kind of reiterate where I see things going here. There are some green shoots out there. Hopefully, we characterize that there still is uncertainty out there. We talked about our measured approach and how we're looking at the volumes. I think what you should take away from this call is clearly the focus is on efficiency mode and driving all the optimization from an operating standpoint, a portfolio standpoint. We're trying to make ourselves as strong as we can, as well as efficient. We're ultimately in a commodity business. Low-cost, reliable supplier partner usually wins in that. That's what you hear about on the optimization side. We've shared a lot on the financial strategy. It's maximizing free cash flow. We've gotten ourselves to a position where we're going to be generating meaningful free cash flow going forward, excluding asset sales. With asset sales, it gives us a little opportunity to jumpstart some additional de-leveraging. It's really the balanced approach to de-leveraging and getting value back to shareholders and unit holders that we really think we're on the right path going forward. We're cautiously optimistic about the future. Oil prices are pretty sturdy. I can tell you one sure thing that happens sometimes. We've always heard the comment about prices fix prices. I think what the North American sector is doing is being very careful not to over-respond, which would create additional problems. I think the whole industry right now is moving forward, but I think it's still some questionable times as we get through global demand coming back, and really getting our arms around the vaccine and getting control of COVID. With that, I'll stop and thank all of you again for your patience this afternoon, and we look forward to chatting with you as we do on an interim basis between calls. Thank you very much. Thank you to you all. I appreciate you hosting today, thank you, each of our investors and analysts for joining to our call today. Thank you. You're very welcome. That does conclude our conference call, everyone. Thank you for your participation. You may now disconnect.