Hello, and welcome to the Clean Energy Fourth Quarter 2021 Earnings Conference Call. All participants will be in listen-only mode. . After today’s presentation, there will be an opportunity to ask questions. . Please note today’s event is being recorded. I would now like to turn the conference over to Robert Vreeland, CFO. Please go ahead.

Thank you, operator. Earlier this afternoon, Clean Energy released financial results for the third quarter and year-ending December 31, 2021. If you did not receive the release, it is available on the Investor Relations section of the company’s Web site at www.cleanenergyfuels.com where the call is also being webcast. There will be a replay available on the Web site for 30 days. Before we begin, we'd like to remind you that some of the information contained in the news release and on this conference call contains forward-looking statements that involve risks, uncertainties and assumptions that are difficult to predict. Words of expression reflecting optimism, satisfaction with current prospects as well as words such as believe, intend, expect, plan, should, anticipate and similar variations identify forward-looking statements, but their absence does not mean that the statement is not forward-looking. Such forward-looking statements are not a guarantee of performance and the company’s actual results could differ materially from those contained in such statements. Several factors that could cause or contribute to such differences are described in detail in the Risk Factors section of Clean Energy’s most recently filed Form 10-Q filed in November 2021 or in our Form 10-K that will be filed later today. These forward-looking statements speak only as of the date of this release. The company undertakes no obligation to publicly update any forward-looking statements or supply new information regarding the circumstances after the date of this release. The company’s non-GAAP EPS and adjusted EBITDA will be reviewed on this call and excludes certain expenses that the company’s management does not believe are indicative of the company’s core business operating results. Non-GAAP financial measures should be considered in addition to results prepared in accordance with GAAP and should not be considered as a substitute for or superior to GAAP results. The directly comparable GAAP information, reasons why management uses non-GAAP information, a definition of non-GAAP EPS and adjusted EBITDA and a reconciliation between those non-GAAP and GAAP figures is provided in the company’s press release, which has been furnished to the SEC on Form 8-K today. With that, I will turn the call over to our President and Chief Executive Officer, Andrew Littlefair.

Thank you, Bob. Good afternoon, everyone. And thank you for joining us. I think my remarks could be a little shorter today because hopefully you were able to watch our RNG Day presentation last month. We went into some detail about our strategy to expand our business by investing in the production of RNG, which allows us to deliver this incredibly clean fuel to a growing customer base. If you haven't been able to watch the presentation, I highly encourage you to do so. A recording of the presentation can be found on the investor page on Clean Energy's website. Despite the country in the world, having to grapple with the COVID pandemics ups and downs throughout 2021, the year ended up being one of the most strategically important since Boone Pickens and I founded Clean Energy 25 years ago. Earlier in the year we established joint ventures with BP and Total Energies to work together and build a steady supply of low carbon RNG for the future. And soon after we signed the company's largest fuel deal ever with Amazon, and our transformation into the leading provider of a negative carbon intensity fuel continued through the remainder of 2021 with the signing of partnerships with some of the country's largest dairies. In the fourth quarter of the year, the company delivered 105 million gallons, which was a 9% increase over the fourth quarter of 2020 and the most gallons we've ever delivered in a quarter in the company's history. We continue to see solid gains and refused to transit while the deployment of Amazon's new fleet began to provide a lift to our heavy-duty truck sector. Our revenue for the quarter was $92 million, an increase of 23% compared to the same quarter in the previous year. Deducting a…

Thank you, Andrew. I’ll recap 2021 and then move into our guidance for 2022. We had a good fourth quarter, particularly with good volumes and volumes, as we all know are very important. But we did see approximately about a $2.5 million negative impact from sustained lower LCFS pricing during the quarter. Our GAAP net loss for the fourth quarter was $2.4 million or a penny a share, while on a non-GAAP basis we had net income for the fourth quarter of $6.4 million or $0.03 a share. Our GAAP net loss for the year was $93 million which was higher than our guidance of $86 million due to non-cash unrealized losses on our zero now fuel hedge some additional stock comp related to stock awards occurring in December, and the lower LCFS pricing that I mentioned. Adjusted EBITDA for the fourth quarter of 2021 was $18 million versus $13.6 million a year ago. And for the year adjusted EBITDA was $57 million. Now we had we maintained and kept our guidance of 60 to 62, on the adjusted EBITDA which we absolutely felt that, that at least, at a minimum, the lower end of that range of 60 was achievable. Had we seen better LCFS pricing during the fourth quarter. But $57 million is a good number. And we're excited about that, and certainly an improvement over last year, which was $45 million. Our revenues of $92 million for the fourth quarter of 2021 were in line with expectations and reflected higher effective prices caused by higher fuel pump prices and continued higher rent prices. Our effective margin per gallon for the fourth quarter was $0.27 a gallon. And for the year, it ended at $0.26 cents per gallon, which was at the high end of our range at…

Yes, thank you. At this time, we will begin the question-and-answer session. And the first question comes from Eric Stine with Craig-Hallum.

Hi, Andrew. Hi, Bob.

Hi, Eric.

Hey. So you mentioned the Amazon effect. Just curious if you can go into that a little bit more in detail, whether I would assume that's more in conversations, when you would anticipate that that might flow through to actual truck orders. And then obviously, there'd be a little bit of a lag but when you might see volumes as a result and then curious your thoughts on whether, Amazon is having some success or is pushing this into their supply chain?

Right. So, Eric, and I think we're seeing that now. We're having conversation with and we know that Cummins is having and the OEMs are having discussions with large fleets now. And so I think you'll begin to see, we're already seeing some uptake in adoption of natural gas right now with some of these large fleets. And I think the announcements by some of these fleets For instance, the one-on-one working with Cummins, we hadn't seen these kinds of announcements really before. So I think they're really important. Also, I think it's important to note that as Amazon is fielded now, well that announcement, or at least that Tweet or text that got out in late last year of the thousands of there's more -- more than that many trucks now. Those trucks are operating extremely well, and they're getting great visibility. And they're moving about there --essentially in 30 states across the country at our stations. And they're getting a lot of use and a lot of visibility. And I think all of that bodes very well. So, the I think the Amazon effect is happening as we speak. The interest in the RNG is never seen that really higher. All of our customers right now want that. And that is part and parcel, as we talk about natural gas engines, or adoption of new trucks and all, it's always hand in glove with the RNG. And so I think all of this is, is because of the success of the Amazon program, we're seeing it right now.

Okay, got it. Maybe just one other. I think on your RNG Day, one of the areas that was a key part of your 5-year plan was switching out O&M customers over to RNG. And, maybe just what you're seeing early success there, how you anticipate that playing out, but then taking it another step? What are the economics look like? Because I would assume that, because it's for someone else who owns the station, they would share in those economics as well. So there actually is an economic benefits were you to make this switch, which I think was something like $90 million of your 5-year EBITDA plan.

Right. So Eric, I'll have Bob join me here as well. But, there's a couple parts to that. So for those that didn't see the RNG Day, there's one concept which was moving RNG negative fuel in California to our existing infrastructure that is already providing RNG but it might be landfill gas. And so there's a pickup. Certainly when we own the supplies, dramatic pickup. Now, what is your question though started with and that number got to be around $70 million to overtime, $70 million $90 million type number. And I think I described in the Wall Street Journal didn't sound very articulate to us. It was like magic. But we're already providing that fuel. And so it's really a switching in the other feedstock. And we have this is better for the bottom line. But the way your question started out was the -- our O&M customers. So now, this is transit customers and refuse customers where we may be providing operation of a station. And we get paid for that on a gallon, but those are good margins for gallons we've said many, many times, but low, low, right, low cents per gallon, let's put it that way. Good margins, low revenue per gallon for us. So when we switch in RNG become a fuel supplier to those customers, which we've always wanted to be able to do. Yes, we do split that with the customer. And if they do own the station, in these cases, they do most often. Yeah, they'll get a larger share than we will. But it's a big upgrade on our margin per gallon going from a fuel provider, with our downstream share in addition to our operation and maintenance. So it's a big pickup for us, it's also a pickup for the customer.

Thanks. Since that answered it, but I was just getting at the fact that I mean, that's a big part of your EBITDA pickup. But I mean there is certainly incentive for the customer to do that. Because the economic incentive is better for them as well. Okay. Absolutely.

Not to mention that it helps them in the area where they operate. They go to a sustainable fleet. So that was in less than less than any of these operators. They're all under pressure. So that's exactly what happened. I'd like to think that New York City Transit was progressive when they put the natural gas buses in versus diesel buses many years ago. And we were doing operation and maintenance but when they asked us to provide the fuel, they got to pick up, they got to share in that. And as we did once we began providing the fuel other than just operations and maintenance. And they're now an envied sustainability climate change contributor there in New York City. That's just a drop in. So that's our that's our own rendition of a drop in fuel is existing natural gas transits then now get to drop in a renewable. Eric, like I said it's like magic.

All right, thanks a lot.

You bet.

Thank you. And the next question comes from Rob Brown with Lake Street Capital Markets.

Good afternoon.

Hey, Rob.

Rob.

Wanted to get an update on the number of RNG projects you have underway? I think, months ago, you had about five, how's that changing? And where are you at in terms of signing up new RNG projects?

No, it's good question. We have about seven farms under construction. We have 10 signed LOI. So those are in the process, they're not under construction yet, but they're headed that way. Then we have 15 to 20 projects, I sort of say are behind those in the pipeline. We have substantial -- we're doing substantial due diligence and discussions with the developers and the farmers. Those 15 to 20 projects will involve 50 dairies. So there's a lot happening right now. And that's a little bit of an increase from 30 days ago. But it's in line with what we talked about on January 26. More projects under construction now than what I talked about in January.

Okay, great, great, great progress. On the CFS pricing that you talked about, Bob how is that changing? And what's sort of the market dynamics there? And you have a sense as to predict, of course, but you have a sense of maybe how that changes over the year?

We got to have it on, on average around 155. And it's a little bit lower than that. So we were anticipating that, there's room to move up there. But, we felt like it was probably at 165 might be a little bit aggressive. And so, I think, I don't know that we see radical change there. I mean, it can I mean, again, we thought in the fourth quarter, there could be a move upward if there was some action by carbon in there, kind of scoping workshops and whatnot. But I think we're kind of fairly steady at about where we think it is that the 155 on average.

I think, Rob, we tend to be long, longer term kind of constructive and bullish on the pricing of the low carbon fuel standard. That's not to say we see some dramatic fly up here. But we think is the scoping. And they look at the success of the program, and they look at the increased obligations in the outer years, we think that the price of the LCFS is could likely move up a bit. So, we thought it was prudent to price it in here, sort of at where we see it today, rather than speculate. But I would think our team believes and we of course, have some experts to help us on this. We think, sort of over the middle term that work constructive on the pricing, and think that it could move up a little bit too.

Great, thanks. I'll turn it over.

Thank you. And our next question comes from Manav Gupta with Credit Suisse.

Hey, Bob and team. Just quick question was, and going back to the Analyst Day RNG Day. And I think you had indicated eventually you would like to be in that about 105 million gallon range by 2026. And just doing some rough math, would it be fair to say you would probably need somewhere like 50-55 Berries somewhere to get to that 105 number --105 million gallon number?

We're crushing around there. I mean, you're at 2 million a dairy so --

It depends. So I think it would be on the terms of the clusters okay. So, you'll have a dairy but you bring in satellite dairies. So, it could actually be higher than that. Because you'll be drawing up smaller, local, smaller dairies. But as I said, these 15-20 project right now, contemplate 15 dairies. So it could be 105 million -- could be in terms of dairies, it could be higher than that.

Okay, fine. Now, the second quick follow up there is, when we go to the cash statements that you provided on the RNG Day, it appears at some point not only to the JV start paying down the debt, they actually start paying you some distribution. So, can you confirm that at what point to the JVs actually start making enough cash? So they actually start paying you guys some form of distribution?

Yeah. And that is -- I want to say it's like 25-26. So, yeah, where you're seeing the debt reduction is because we're seeing distributions come in from --

From the JVs.

From the JVs. Because -- and it's principally 25 and 26, there could be a little bit in 24. The more meanings.

Perfect. And the last quick question here is, you were doing about $13 million $14 million in EBITDA. Now you hit over 18. Next year’s guidance is doing more like 16. And I think you mentioned a few factors. Why it's going to be moving down from 18 to 16. But if you could just help us bridge the gap why are we moving down from $18 million a quarter now EBITDA to about 16 number?

Yeah. So in the fourth quarter that 18, we had about $4 million earnout in the 18 in the fourth quarter from our sale of upstream supply to BP and we've had that for five years. And which was a question that we had about, actually, how are we going to get to we were anticipating we could get to 20 in the fourth quarter and we got to 18. So -- and then I mean, our -- so we should not see that kind of radical bump in the fourth quarter for something like that. Our volume tends to grow during the year, because of fleet rollouts and adoption it just -- doesn't all happen, say January 1. And then I think the other thing that I was just being careful with on the on the $16 million is that has the alternative fuel tax credit in there. But you don't want to put that evenly in Q1 and Q2 for the alternative. So you ended up having to -- you would end up taking the alternative fuel tax credit so let's say out of the 65. So you would get 2 out of 40 -- what's that $44 million, which is kind of 11-ish, Q1, Q2, but then Q3, you're going to see about 11 plus maybe even $15 million of AFTC. And then 11 plus 5 in Q4. So, I don't give guidance on the quarters, though.

That was actually super helpful. Thank you so much.

Maybe I just did.

Thank you.

What I considered Manav. I was doing math. Thank you. But it is important. Thanks for the question. Because it's -- the FTC and a quarter is significant. If you just do the math, you're not going to be happy. So --

I'll turn it over. Thank you, guys.

Yeah.

Thank you. And the next question comes from Pavel Molchanov with Raymond James.

Thanks for taking the question. You guys mentioned just a few moments ago, the need to kind of back out the IT or the AFTC in the first couple quarters of the year. Going back to what we talked about during the webinar one month ago. Any incremental thoughts on whether the tax credit will be revived in some form in this congressional session?

So I think Pavel, just for the group, I think you're saying did -- would they change it to add in some sort of renewable natural gas credit?

I just make more broadly is there any in the last six weeks since you did the last investor call? Is there any movement in DC on the reinstatement of the tax credit?

I don't think there's been any movement in DC on any of these legislation in the last six weeks. So no, I don't think though. I really think -- I mean, other than Supreme Court Justice nominee or something. I don't think there's been any. I think that the House is trying to figure out just what pieces of a bill that they can assemble, they haven't decided on that yet. And just what style that'll take. But I don't think so yet, Pavel. Now, that doesn't lead me to believe that it's not going to happen. I still feel like, as I mentioned before, that our particular alternative fuel tax credit amongst many other things, okay. It's not the only thing will end up being in some sort of tax title at some point when they begin to fashion different pieces of legislation. And, that remains to be seen what how that all comes together. But it will, it should. The reason I feel pretty confident on it is we've had that tax credit for the last -- I don't know, 10 or 12 years can't remember which. And it was identified during -- with the two Chairman from the tax committees in the Senate, the ranking in the minority as one of the non-controversial titles. So it doesn't appear to be in kind of the lightning rod bucket. And so I think that when they figure out kind of how this whole thing is going to come together, I'm guessing later in the year, you'll see that as part of some sort of Tax title, some point.

Okay. Maybe follow up with kind of a macro question. So we're almost exactly two years from the start of the pandemic. And you guys have very good insights into what's happening in fleet based transport of the market segments that you sell into. So refuse trucks, urban transit, airports, maybe a few other markets, is everything back to pre-COVID levels or not quite?

Yeah, I would say we essentially -- is you and I've talked about this before. We did see a little bit of a late-December, it's kind of hard to tell. Because those holidays, put a little in our transit. Customers, especially holidays impacts it a little more significantly in those that week or so than you would think. But I think we detect in late-December and early January, we saw a little bit of the Omicron there were some -- there was a five week four week blip. But having said that, I would say that airports in general, as they came up into December, just about right back, and transit as well. We've may have seen three or four weeks there at the end last couple of December and early January where it came off just a tad. But I think to answer your question is yeah, it looks to me like we're back to pre-COVID levels. All of our sectors came back.

Okay, including airports?

Yeah. They can still be off a tad, but pretty close.

Okay. Great insights. Thank you, guys.

Yeah, you bet.

Thank you. And our next question comes from Greg Wasikowski of Webber Research.

Hey, good afternoon, guys. How you doing?

Good.

How are you, Greg?

Great. Doing great, thanks. A couple higher level questions on fleet transition activity and then one on hydrogen. I'll start with the fleet transitions just curious outside of regions with the LCFS credit programs, in what states or specific regions or municipalities are you seeing the most fleet transition activity from diesel to gas? And then like similar question, but along the lines of the application, whether it be transit bus refuse truck or specific heavy-duty class of truck?

Well, okay. So, generally, I would say the fleet transition at all the fleets is, we always see quite a bit of interest in Texas, in the Southeastern United States is where you see a lot of trucking. And then in the Northeastern United States, we particularly see a lot of interest on the refuse side. And so it kind of -- I kind of almost named all the parts of the country, but Texas, Southeastern United States, Northeast, a lot activity on refuse trailing that a little bit is the Midwest. And then of course, the West, the West is always strong, Southwestern United States. I mean, that's a strong. But that was covered in your low carbon fuel. Now, we are seeing uptake on RNG in 30 some odd states right now. So it's not just a California thing. And it's not just regional, it's beginning to be pieced together all across country.

Yeah, okay. No, I appreciate that. And then maybe similar, but asking in a different way. What's the again -- in the non LCFS states and regions, what's the main catalyst for end users fleet owners in the decision transitioning from diesel to gas? Is the primary focus on the price of diesel or is it CNG accessibility, internal decarbonization goals, public pressure? Like what are you seeing the most outside of that LCFS state and region?

Well, now you've identified it. I mean, I think it's always been -- it's been similar. The sustainability and low carbon pieces obviously, is a bigger driver today than before. But underlying it -- I think you're right, Greg. Underlying it though, is always a sense of economics. You don't often see -- you certainly don't see private fleets just step into to step into something knowingly, it's a lot more expensive. Now, they're beginning to get more support from their either their customers or their -- the public, on their sustainability goals. And so they're willing to -- I think they're willing to, you know, take let's call it more risk, and more cost. Now, public transit. Public transit, and public agencies are certainly being for instance, DFW, it's very important for them to try to mitigate and have what they consider to be one of the cleanest, low carbon airports in the world. And the transportation piece of this is very important. And then there's not a lot they can do about airplanes. So the transportation part of it was very important. And that's why they really pushed hard on RNG. And I think our friends in Dallas Area Rapid Transit, think the sustainability part was really important for them to go to natural gas, and now RNG. So it's incremental a little bit. Cost is always important. But this environmental piece is, is getting to be a bigger, bigger driver. So I don't know that that helps you at all. But we're seeing a lot of that. They understand. -- I mean the when this happens, it's a federal program. So right.

Right. Okay, that's helpful. And then one more on hydrogen, if I could. Andrew, you spoken about hydrogen and fuel cells and transportation in the past. But I was wondering if you could compare and contrast hydrogen fuel cells versus hydrogen combustion. Cummins spoke about it during their Analyst Day hydrogen ice. And some other players have talked about it for certain applications. Does that come up in your conversations with customers and end users at all? And then from Seoni’s perspective, do you have any preference one way or the other? If it's a fuel cell electric vehicle, or through burning hydrogen directly? Or is it really all the same to you?

First, it never comes up with a customer. So I don't know who's interested in it. But we don't ever hear that much from a customer. Occasionally, you'll hear it from a transit customer. And I always want to remind you why that is. And it's -- I think they feel it's a part of their duty, because they're funded by 100% from the federal government on these kinds of projects, is that they're a testbed. And so you see transit agencies do this. We've got five new -- we've got five more RFPs coming down the track right now. It's usually about 15 to 20 vehicles out of a fleet of several 100, super expensive tests. These are hydrogen fuel cell buses. So you'll see the transit agencies do it because they think that's part of their social compact with getting free money from the feds is to be able to do this kind of thing. Private sector is not serious about it yet, so we don't really hear that. Now, in terms of the -- look, I'm not an expert on all this. But I have said, and I do think we'll end up being somewhat right on the fact that we think that RNG will be a very viable green, renewable feedstock. And it's a bit will be available using the nation's pipeline system. This idea that you're somehow going to put in a new hydrogen delivery system, I just don't think that's going to happen. I think that that could be 50 years in the making. By the time you build plants, and you start hauling hydrogen around pipelines of hydrogen, I mean, that is a really a tall task. So I think the way that it will happen in the bridging to it for hydrogen, will be through a fuels -- transfer of the fuel that will be transported using the delivery system that's already put in place in the United States. I have to think in the early next 5-10-15 years, that'll be RNG that will be reformed at the stations. And I'm not sure Greg, if it'll end up being somehow put in a combusted as a high theme, a blend of hydrogen or if it ends up being put into a fuel cell. I think the RNG will be the feedstock for the foreseeable future. And somehow, maybe it gets blended with some hydrogen perhaps. This hydrogen thing is very expensive. People kind of casual about it, but it's very expensive. So I look at the -- we're -- we have 50 salesmen that talk to fleet operators every day that are very interested in the bottom line. And I don't see how hydrogen fits into that at all.

All right, I always appreciate your color on that, Andrew. Thank you, guys very much. I'll turn it over.

Thank you. And our next question I comes from Craig Shere with Tuohy Brothers.

Hi. I just want to clarify on this JV distribution, so upstream to the partners by the decade 25-26, maybe starting at the end of ‘24. How should we think about this in terms of self-funding? And any decline rate, equity contribution partners left to make over the next couple of years?

Well, Craig, I think we kind of -- I'll say, we laid that out somewhat in on the RNG Day. So, at some point there, we probably will get to self-funding. And, it's kind of the -- at the portfolio project level. I think in our model, at least what we laid out for the five year plan is we were being fairly simplistic and not getting. We were not going down a variety of kind of capital structure avenues. And so we kept it fairly simple of cash needed cash in cash comes out, we could pay it. But frankly we'll be able to lever projects and so there's not -- not in anticipation on our part of kind of blowing up this case with added equity and that sort of analysis. But we weren't going to lay out five year capital structure plan on that. And we’re just kind of took their EBITDA. And it's just that's distribution available to the corporate, in which case we'll pay down some -- will start paying down corporate debt. We've kind of funded it through -- at the Clean Energy Corporate level, would really be kind of how we would lever those deals. That could be at the project someday.

Got it. And this ratio. I don't know if this is what you had in mind originally, but sounds like it could be 3 or 4 to 1 on the projects and number of dairies feeding into the projects? Are you finding as you get deeper and deeper in this with your JV partners that you're finding more and more ways to lower the all in unit costs delivered? Just get more operating leverage than originally thought.

We're looking. I don't know, things are little early on.

Yeah, I think it's a little early, Craig. I mean, we -- our view is there'll be some synergies and some efficiencies. I think the some of these early projects have been right in the middle of supply chain and still some increased cost. So our hunch , and our view is that some of those costs will come in. And I feel fairly certain of that. But I would say through the projects that have been underway in the last three-four months, that we've come up with dramatic cost reductions, yeah.

But we're certainly -- we’re on that path of that kind of mindset and thinking and hiring the right people. Very mindful of this is -- this should be kind of repetitive. I mean, all farms and families around those are different, of course. But, the basic setups, I think have room for -- the industry, trying to standardize, tanks, and the membrane technologies and the cleanup technologies. All that's coming into play, we did that. We've done this on the station five years ago. It used to be that every station was built. It wasn't until that we understood the inlet pressure at given location that we then went and design the compressor, totally unique. It was a work of art each one. And we stopped that 15 years ago, 20 years ago. And the same thing will happen here as we get better at it and do more of these

Fair enough. Appreciated. Thank you.

Thank you. The next question comes from Matthew Marra with Tudor, Pickering, Holt.

Hey good morning, Andrew and Bob. Bob. I was hoping you could share Clean’s revenue from the LCFS either in the fourth quarter. I don't know you might have a full year number. I think that was it was $5.7 million in Q3. Do you have the Q4 number?

It was 3.8.

Great, thank you. And then unfortunately, it looks like the New Mexico LCFS bill failed and in the State Senate this week after passing their State House earlier in the week. I know it's hard to predict politics. But are you expecting any other states to pass a LCFS program this year? And if so, which ones are on your radar?

Well, I was so I'm still hopeful that New York, they're wrestling with it now. This is not easy there either. They're in the throes of it looks to me, like we have a fairly nice setup in terms of co-sponsors in both the House and the Senate there, the assembly and the Senate. But we have more work to do there with the governor and with particular governing chairman there. So more there. I would say it was New Mexico and New York that were the closest in terms of ready to pass type legislation. And then there's six or eight -- I don't have it right here in front of me, Matthew, but we've had discussions and our industry associations and players have had discussions in Illinois and Michigan and other states in New Jersey and others. But I'd say they're all a year behind. I think the way we should all think about it is that these are likely -- these are likely kind of two year type bills. Now that -- look, you're putting in a whole new regime of regulation and obligations for industry. And also this isn't like passing a seatbelt mandate or a motorcycle helmet mandate. I mean, there's a little more to do it than that on this and lots of interests at stake. And so it's reasonable to think that these are -- take some fulsome discussion and often in state legislatures that takes two years.

Got it. Thank you very much.

There has been -- maybe this is a good place to put it in. I am starting to read for the first time a carbon, like an RFS a carbon fuel credit system national. That is starting to percolate up from the industry associations to the different groups in Congress. And I'm imagining next stop administration, there'll be a lot of work to be done there, too. But that's the first -- I've always wondered why you wouldn't have sort of a national federal carbon fuel program, like the RIN. That sort of makes sense to me. And just this week, I'm starting to read about some of the industry solicitation making those pitches to members of Congress and the administration. So stay tuned on that, too.

Great, thank you.

Thank you. And next question comes from Jason Gabelman with Cowen.

Yeah, hey. Thanks for taking my questions. I first want to ask about the RNG production ramp up that you provided during the RNG day. There was a dark green bar showing the RNG that's under LOIs. Can you just discuss what kind of rate of conversion you have from LOIs to getting these projects executed and into the construction phase?

We know early in this we've had a very high hit rate, 90%

Got it. Is there -- I mean, would you say that a lot of farms that you're pitching, do you see a lot of competition on them? Or are you mostly the only --

No, we're seeing competition. I wouldn't say, it's not quite like RFP. But no, we’re -- these farmers have heard from land -- let's call them the land men and women and developers. I think that Wall Street Journal story the other day talked about somebody that saying that the particular farmer had 10 different people. And so we're seeing some of that. But, what I said on RNG Day, I think is true. And humbly, we like our go to market sort of face here. We're in the business. We've been in the RNG business one way or another, not necessarily at the dairy level, but for a long time, 14 years. We've worked with our partners, Total and BP in this business for a long time. Our partners have deep pockets. And, we have financial capability as well, we have a long-term offtake interest. A lot of these farmers have heard about us for a long time. So we have a reputation and they know we have a national distribution system. So we like -- we're not really afraid of competing, because we think we have a lot to offer. And we -- as you can tell by the pipeline and all that we've been in the business now nine months. And our hit rate -- we're able to move nimbly. And so we like our -- we won't get every deal. Of course not. But we like our conversion rate, and we like our chances.

I also wanted to ask about California has LCFS program. I know we previously discussed that the petition to remove RNG from the LCFS program was denied. But I believe it's still being discussed within the scoping plan that's ongoing this year. Can you just talked about what you're hearing coming out of carb right now? And the appetite to amend if at all, the carbon intensity or carbon -- or LCFS credits that are generated from RNG?

The last -- I think the most current thing that I've seen from the ARB -- and we have people to work this real closely. But the most current thing is to public statements from the ARB and one and, the CANet Papers and the other in the Wall Street Journal saying they like the program.

And it’s working.

And it's working. Now, they didn't have to say that, and they get those things cleared. And so I think that's a fairly strong public statement that happened in the last couple of days. Now, look, the petition you're talking about is a letter from the Environmental Justice Community, and that's not going to go away that you're going to see that continuing. But what I think has happened on that particular interest, which is moving dairy farms out of the State of California, if you really want to understand what that really means is no dairy cows in California, that's what was really what we're trying to get at here. And so that was referred to the scoping, which is -- let's -- we deny your request here. And let's talk about this later in another discussions format, in another period. So I think this probably is not the last we've ever heard of that. But I think the fact is that the program is working. The situation is you're capturing a lot of methane that you otherwise weren't capturing. And so it's nothing like success here.

Got it. And if I could squeeze just one more in. Just want to ask if -- do you see any benefit in your business from California's cap and trade program? Are you able to capture any value given that those credits are moving higher?

Not really. I mean we're probably a little more on the on the receiving end of the cost, if you will. Because we have a little bit of some of our stuff like say our LNG plant and things like that, that come under cap and trade. And so we've -- so -- but it's a hard one to necessarily complained about because frankly, I'm also quite happy when the LCFS is at 200. So yeah, so we're not benefiting from it. And it has been a little bit of a cost to us. But relatively speaking, we have a very small footprint when it comes to that. So we're not talking about really -- even really big bucks. But we've noticed that.

All right, super. Thanks for all the all the answers.

Okay, thank you.

Thank you.

Thank you. And this concludes the question-and-answer session. Now I’d like to turn the floor over to Andrew Littlefair for any closing comments.

Operator, thank you. And thank you all for joining us today. We look forward to updating you on our next quarter.

Thank you. The conference has concluded. Thank you for attending today's presentation. You may now disconnect your lines.