Canadian Natural Resources Limited

Good morning. We would like to welcome everyone to the Canadian Natural Resources 2021 Second Quarter Earnings Conference Call and Webcast. After the presentation, we will conduct a question and answer session. Instructions will be given at that time. Please note that this call is being recorded today, August 5, 2021, at 9 a.m. Mountain Time. I would now like to turn the meeting over to your host for today's call, Corey Beaver, Executive Advisor. Please go ahead, sir.

Thank you, operator, and good morning, everyone, and welcome to Canadian Natural's second quarter 2021 corporate update conference call. Canadian Natural had another strong quarter, financially and operationally. As I've commented before, I believe our asset base is unique amongst our peer group, underpinned by long-life, low-decline assets and complemented by our conventional assets that allow significant flexibility, all of which can generate significant free cash flow. Beyond our robust asset base, there is a corporate strategy that focuses on generating real returns for shareholders and a driven management team and a corporate culture that focuses on being effective and efficient. Over the years, Canadian Natural has clearly demonstrated its robustness, sustainability, and the strength of its business plan. For 2021 and beyond, I believe we're one of only a few companies capable of delivering meaningful economic growth increasing returns to shareholders, and reducing absolute debt in a responsible manner. And as both Tim and Mark will discuss, we're pleased to provide additional clarity on how our substantial future free cash flows will be dispersed amongst our four pillars. For today's call, Tim McKay, our president, will first provide a corporate update. Then Mark Stainthorpe, our chief financial officer, will then provide an update on our 2021 financial outlook as well as our strong financial position. Tim will then provide a summary prior to opening up for questions. Before we kick off, I'd like to remind you of our forward-looking statements. Of note in our reporting disclosures is that everything will be in Canadian dollars unless otherwise stated, and as well, we report our reserves and production before royalties. I would also suggest you review our comments on non-GAAP disclosures. So with that, I'll turn it over to you, Tim.

Thank you, Corey. Good morning, everyone. Canadian Natural delivered strong operational results in the second quarter. as we achieved quarterly production of approximately 1.142 million BEOEs per day as a result of our long life, robust, low decline assets, operational excellence, and with our capital discipline generated significant free cash flow. We balanced free cash flow to our four pillars of capital allocation, maximizing value for our shareholders. In the first two quarters of 2021, we have reduced net debt by $3.1 billion, returned approximately $1.3 billion to our shareholders through dividends and share repurchases, maintained capital adjustment, executed on opportunistic transactions, which will add long-term value. The strengths of Kenya Natural's business model are also applied to environmental, social, and governance to deliver industry-leading performance across the board, a significant factor in our long-term sustainability. For the period from 2016 to 2020, in our oil sands operation, our GHG intensity is down 38%. North American E&P methane emissions are down 28%. And corporately in this time, we have taken equivalent to over 1 million cars off the road annually. And over and above, we are the leading capture and sequester of CO2 in the oil and gas sector worldwide. Our safety record is top tier as a corporate total recordable industry frequency improved to 0.21 in 2020, a reduction of 58% from 2016 levels. In June, we announced the Oil Sands Pathway to Net Zero initiative, an alliance of oil sands industry participants who have a goal of achieving net zero emissions in the oil sands operations by 2050. This is an important initiative, and the oil sands industry participants at Canadian Natural will further strengthen our leading ESG performance while delivering meaningful emission reductions and balancing sustainable economic development. And we'll require collaboration with the federal and Alberta governments so that together we can help achieve Canada's climate goals. With the positive outlook for commodity prices for 2021, we have increased our annual capital budget by $275 million. The breakdown is as follows. Our conventional and unconventional budget has increased by $120 million dollars, primarily for additional drilling of 78 wells and development activities, with a targeted capital efficiency of approximately $8,400 per flowing BUE, and giving us the 2021 exit rate of approximately 14,000 BUEs per day. $110 million is related to long life, low decline assets, of which $75 million primarily relates to the additional scope completed and the extended turnaround time to complete the horizon turnaround in the second quarter. $35 million of the $110 is for construction of three pads at Primrose, two at Kirby North and two at Kirby South, which will support production additions in 2022 and beyond. Our area-based abandonment program has been highly cost-effective, and as a result, we have added an additional $45 million to our 2021 capital budget and target to do an additional 800 well abandonments as we continue to prudently manage our liabilities and environmental footprint. All of these additional expenders will result in an estimated increase of about 1,500 jobs across Alberta, British Columbia, and Saskatchewan. Moving to the assets and starting with natural gas, overall Q2 production was 1.614 BCF per day, an increase from our Q1 production of 1.598 BCF per day, with North American Q2 natural gas production of 1.591 BCF up from Q1 of 1.581 BCF. 5, even though Pine River, approximately 100 million a day, was down for the full quarter. As of July 24th, the plant resumed operation and is currently producing approximately 100 million a day. We continue to focus on operational excellence, and in our Q2, North American natural gas operating costs were strong at $1.15 versus Q1 of $1.24 per MCF. At Septimus, a 5-net well pad came on stream in June, as budgeted with total current rates limited to approximately $30 million a day of natural gas. It had a strong capital efficiency of approximately $5,000 per flowing BUE. Septimus is now at full capacity at approximately $150 million a day of natural gas and 9,000 barrels a day of liquids, and targets to remain at full capacity for the remainder of 2021. A Townsend six-wall pad came on stream in June on time and cost. with toll rates of approximately 55 million cubic feet of natural gas, with strong capital efficiencies of approximately $4,000 per flowing BUE. Production at Townsend is approximately 265 million cubic feet of natural gas, was achieved in the second quarter, and remains on target to exit 2021 at a production rate of approximately 340 million cubic feet per day. Looking to the second half of 2021, ACO strip prices continues to look strong at over $3.50 per GJ, improving the economics of our natural gas projects, adding more value to our natural gas production as we revised our target natural gas guidance up to 1.68 BCF per day to 1.72 BCF and target exit 2021 in excess of 1.8 BCF per day. Our Q2 North American light oil and NGL production with 98,559 barrels per day, up 6% from Q1 2021. Primarily as a result of the company's drilling and development activities, Q2 operating costs decreased to $14.39 per barrel versus Q1 operating costs of $16.07 per barrel. The company continues to advance its high-value Montney light crude oil development at Wembley, where 13 net wells have been drilled to date, ahead of schedule, under cost. of the budgeted 18 net wells targeted to be on stream in 2021. Cost efficiencies have been realized on the Wimbley drilling and targeting costs are 12% lower than budgeted levels, resulting in strong capital efficiencies of approximately $8,300 per flowing BOE once on stream. Construction of the new crude oil battery and gathering system has been top tier and is approximately 45 days ahead of schedule and is now targeted to be on stream in mid-August with costs targeted to be under budget by 11%. This project is targeted to exit 2021 with total production rates of approximately 8,500 barrels a day of liquids and 30 million cubic feet of natural gas. The international E&P crude oil production averaged 32,697 barrels per day in Q2 2021, a decrease of 26% from Q2 20 levels and a 3% increase from Q1 2021 levels. The changes in production from prior periods are primarily a result of planned maintenance activities, natural field declines, and the permanent shut-in of the battlefields in 2020. Crude oil operating costs increased from prior periods primarily due to lower volumes and as a result of planned maintenance activities in the North Sea and offshore Africa, as well as increased GHG and energy costs in the North Sea. Q2 heavy oil production was up to approximately 66,000 barrels a day. versus the 62,700 barrels a day in Q1, primarily as a result of the company's drilling and, to a lesser extent, increased development activities related to higher prices in the quarter. Future operating costs increased to $19.32 per barrel from Q1 operating costs of $18.89 per barrel. At the company's Clearwater play at Smith, six net horizontal multilaterals are now on Production from these wells continues to be strong, currently totaling approximately 2,200 barrels per day, exceeding budget rates by 600 barrels per day. As part of an additional capital, the company is targeting to drill 70 additional heavy oil wells, which includes another pad of six net horizontal multi-well laterals at Smith and will be drilled and come on stream in Q4. This pad is also targeting strong productive rates of approximately 2,000 barrels per day. A key component of our long-life low-decline assets is our world-class pelican pool. Our leading-edge polymer flood continues to deliver significant value. Second quarter production was 55,212 barrels per day, comparable to the first quarter of approximately 55,500, primarily as a result of the well-drilling program activities in the quarter, offset by natural field declines. Operating costs continue to be very strong at $690 per barrel versus Q1 operating costs at $738 per barrel. During the quarter, the company brought on stream 10 net wells, which has a current production capacity of approximately 1,300 barrels a day, and low capital efficiencies of $9,900 per flowing BUE. Our team at Pelican continues to drive operational excellence, and with our low decline and very low operating costs, Pelican Lake continues to have excellent netbacks. Our second quarter of thermal production was 258,551 barrels a day, down 3% from Q1. Operating costs in Q2 were 3% higher at $11.78 per barrel versus Q1 operating costs of $11.40 per barrel, primarily due to lower volumes in the quarter. At Primrose, the steam flood area, a solvent injection pilot is on track to commence in Q4-21, and similar to the first pilot at Kirby South, This is target to operate for a two-year period. At our oil sands mining operations, we had a strong second quarter with production of 361,707 barrels per day, inclusive of the planned maintenance at Horizon and Scotford in the quarter, with strong operating costs of 25.46 per barrel of SCL. Our teams continue to leverage technical expertise between the two sites, services, operating efficiencies, driving our costs down with consistency. The company's focus on continuous improvement initiatives delivered high utilization and reliability at the company's oil sands mining and upgrading assets. As a result, a record monthly SEO production of approximately 495,100 barrels a day was achieved in June 21, an increase from the previous record of approximately 490,800 barrels a day of SEO in December 2020. I will now turn it over to Mark for a financial review.

Thanks, Tim, and good morning, everyone. The second quarter was a strong operational and financially, delivering net earnings of $1.55 billion, significant adjusted funds flow of $3.05 billion, and free cash flow of approximately $1.5 billion after capital and dividends in the quarter, excluding acquisitions. As a result of the significant free cash flow generation, our net debt balance at Q2 2021 of $18.2 billion is down $3.1 billion from the end of 2020, and the net debt reduction from Q1 2021 was approximately $1.7 billion. This debt reduction includes the full repayment and cancellation of our Devin acquisition term facility of $2.125 billion in the quarter. We have also exercised the par call option on our bonds due in November to repay early in August, resulting in interest cost savings and further absolute debt reduction. Additionally, up to August 4th, we have returned over $1.5 billion to shareholders in 2021 by way of our dividend that was increased in Q1 and through share repurchases. Our long life low decline assets support a sustainable, growing, and predictable dividend. This was evident through the period of challenging commodity prices in 2020, where we increased and maintained our dividend with a further increase in March of 2021. marking the 21st year of dividend increases. We continue to maintain significant liquidity, including revolving bank facilities, cash and short-term investments. Liquidity at Q2 2021 was approximately $5.6 billion. We had approximately $680 million in commercial paper, for which we reserved capacity under revolving facilities. Free cash flow generation in 2021, defined as adjusted funds flow, less budgeted capital and dividends, is targeted to be substantial. and using an annual average WTI of approximately US $66 a barrel, free cash flow is targeted to range between 7.2 billion to 7.7 billion. As a result of this strong free cash flow and increasing balance sheet strength through 2021, the Board of Directors has revised our share repurchase policy effective July 1st, 2021, and authorized management to increase returns to shareholders through incremental share repurchases of approximately 1% of shares outstanding or approximately 11 million shares per quarter. Additionally, the new policy provides that once the company reaches an absolute debt level of 15 billion, currently targeted to occur in Q4 of 21, 50% of free cash flow is targeted to be allocated to share repurchases, with the remaining 50% allocated to further strengthening the company's balance sheet. This provides balance to our four pillars of capital allocation, with increased returns to shareholders, further debt reductions, the ability to provide economic resource development and execute on opportunistic acquisitions. This clearly demonstrates the sustainability of our business model, the ability of our unique, long-life, low-decline asset base with low-maintenance capital requirements and effective and efficient operations to generate significant free cash flow. With that, I'll turn it back to you, Tim.

Thank you, Mark. Canadian Natural's ability to deliver significant, sustainable cash flow is driven by our effective and efficient operations are high-quality, long-life, low-decline assets that have low maintenance capital and significant reserves. Canadian Natural's advantage is our ability to effectively allocate cash flow to our four pillars. We balanced our commodities in Q2 21 with approximately 43% of our BOEs, light crude oil, SCO, 34% heavy, and 23% natural gas, which gives us exposure to all improving commodity prices. and we have increased our annual production guidance target to 1.220 million BOEs to 1.267 million BOEs per day. We will continue to allocate cash flow to our four pillars in a disciplined manner, maximizing value for our shareholders, which is all driven by effective capital allocation, effective and efficient operations, and by our teams who deliver top-tier results. In March, our dividend was increased by 11%, and we have 21 years of consecutive dividend increases at a gaggle of 20% during that time. Effective July 1, 2020, the board has authorized management to repurchase 1% of the common outstanding shares per quarter, and then once net debt is below $15 billion, allocate free cash flow defined as adjusted fund flows, less budgeted capital and dividends, 50% to repurchasing shares, and 50% to strengthening our balance sheet. As we have achieved our interim environmental targets, we have set new targets. By 2030, reduce methane emissions by 50% from 2016 baseline. By 2026, reduce in situ freshwater and mining freshwater river water usage intensity by 40% from our 2017 baseline, as well With our oil sands pathway to net zero initiative, we will work with our industry partners to advance key milestones as we work towards our goal of net zero in the oil sands by 2050. In summary, we continue to focus on safe, reliable operations, reducing our environmental footprint, enhancing our top tier operations. Canadian Natural is delivering top tier cash flow generation. We are unique, sustainable, robust, and clearly demonstrate the ability to deliver returns to our shareholders by balancing our four pillars. That concludes our Q2 call. I will now open the line for questions.

If you have a question, press star 1 on your telephone keypad. Your first question is from Greg Party with RBC Capital Markets.

Thanks. Good morning. Thanks for the rundown, guys. A couple questions for you. The first one is just on Horizon AOSP. I'm just wondering how anomalous was the 495,000 barrels a day in June, or is that something that is setting up more of an achievable number on a sustained basis? Just curious there.

Yeah, that's exactly what it's doing for us, Greg. In the last six months here, you've seen continuous improvement from the 491 roughly to the 495. That's exactly what it's all about. It's about little increments that we're doing on the two sites to improve our reliability, enhance our predictability on our production. So there you can, over a long period of time, the goal is to get closer and closer to those numbers on a sustainable basis.

Okay, and does that have much bearing then on your operating costs, or is this something where it'll allow you to absorb either higher gas prices or higher power prices?

Yeah, well, you know, operationally, those incremental barrels are very, very, very low in terms of cost efficiency. So, yeah, it will help absorb some of the cost of fuel and some of the commodity inflations we're seeing with the various, you know, labor and steel and such. So, yeah, it actually just helps mitigate that and, you know, drive those costs continually down in the oil sands.

Okay, terrific. And last one for me is, you know, you made changes with the Northwest Upgrader site. We understand the financial bearing and so forth, but what's happening there operationally? You've got an equity interest. We hear about it frequently, but we don't really have a good view as to what's going on. Are you guys becoming more operationally involved at the Northwest Upgrader?

Yes, I would say that's correct. What we've done is we've seconded one of our operational persons from Horizon who is very capable to help that operation to become more reliable, get higher utilization. And obviously, you know, it will take some time. But, yes, we have just conned a Canadian natural person into that role, and we're going to help that operation improve, which we expect over time will generate some cash.

Okay, terrific. Thanks very much.

Okay, thanks, Rick.

The next question is from Neil Mehta with Goldman Sachs.

Good morning guys. A lot of cash in the guidance here this morning. Good to see. So a couple of questions related to that. The first one is, um, capital spending, uh, you guys picked up, um, that level this year on the back of some financing that came through any early flavors around 2022. Um, Should we be thinking in that $3.5 billion to $4 billion fairway, or do you think that there's upside or downside to that number? And then I had a follow-up question around the dividend.

Yeah, it's too early. You know, we traditionally do our capital budget here in the fall where we rank all the different commodities and then look at what the port pricing at that time and try and be prudent with our capital budget. So it's too early to say. I mean, if you go back in time, When we started 2021, our capital budget was based on 45 WTI and 250. So, you know, the little bit of increase in capital spending, to me, is just an opportunistic opportunity here just to, you know, tether in some additional capital. It keeps some of the activities that we're doing very well going here, you know, more efficiently. So, to me, it's just too early to say I'm not.

And your view of sustaining CapEx again? Just remind us, Tim, where do you think the level is to keep production flat?

Well, it's in that three to three and a half. Always depends on the types of activities we do in that year. This year it was three. And so to me, it's just generally in that range.

Okay. Okay. The follow-up is just around the dividend. As you said, you have a long track record of raising it. Any thoughts given the amount of cash in the model in the back half of the year of doing another dividend raise later this year? And just thoughts on the dividend growth profile on a go-forward basis.

Hi, Neil. It's Mark. Thanks for the question. The dividend, as you mentioned, has increased 21 straight years. It's been growing and it's predictable. And the board has typically always raised that and done it in the March timeframe. As you see the free cash flow in 2021 and going into 2022, it's significant. So there'll be plenty of opportunity for the board to look at that and continue that growing dividend strategy. The free cash flow allocation policy that's come out here is really because that debt repayment has accelerated so much in 2021. The $15 billion target in Q4 comes fast. So I think that the additional returns to shareholders just gives more balance to the capital allocation of our four pillars going through the rest of the year here. So I think that dividend gets revisited at a regular time in that predictable period.

Okay, perfect. Thanks, guys.

Okay. The next question is from Manit Gupta with Credit Suisse.

Manit Gupta- Hey, guys. First of all, you always have a very informed view on apportionments, egress capacity as it relates to Line 3, where the inventories are. what your near-term outlook for differentials is, if you could give us some of those details.

Sure. If you look at today, apportionment is high. Record high is actually at around 52%, 54%. There is some maintenance being done on the Line 3. But obviously, every barrel is flowing. The inventory levels in Alberta have been pretty steady at the 35 range. And then, of course, the differentials have been extremely strong at less than 20% of WTI. So we look going ahead with the view that Line 3 will come on in Q4, give us that extra capacity. And as TMX continues to progress in 2023, You don't expect that line to come on as well. So we're very positive today here that things are moving in the right direction.

Okay, and a quick clarification here, sir. The revised guidance of discretionary that is post-dividend cash flow went from 5.7, 6.2 to 7.7. Besides the change in oil price tech, was there anything else which drove the increase? cost production or it was just simple as change in price deck?

No, it's mostly the change in price deck as well as continued reliable operations targeted for the rest of the year.

Thank you for the clarification and thank you for taking my questions. Thank you.

Your next question is from Roger Reed with Wells Fargo.

Good morning. Just would like to follow up a little bit on some of the, I guess let's call them medium to longer-term goals on the emissions reductions. When do you think the CapEx gets spent on those, or is it already happening? Is it going to be parceled out kind of on a rateable basis to the various years of targets? And then the other part of that question is, What do you think some of the ancillary benefits are in terms of improved operations, improved returns, overall better cash flows? Like, just kind of think about it as something other than a regulatory-driven event. What are some of the other upside opportunities there?

Yeah, you know, it's early to say. We've only really started the high-level conceptual basis on the on the trunk line and the sites that are going in. Our teams have evaluated different technologies in terms of what we think is the most cost-efficient in terms of reducing our CO2s on sites. So, you know, right now it's very early in the process. You know, we've got to do a lot of engineering work. We have to basically, you know, on the engineering side, come up with the appropriate cost estimates. So to me it's just too early to – there. I mean, the real benefit at the end of the day is what we're looking to do is to be net zero in the oil sands by 2050. And, you know, to me, it's just, you know, we've got to step through it. And as we've talked about, as we move through the process, we'll come up with milestones and give more clarity on CAS costs and how they're allocated between the different partners and the initiatives. So it's just really too early to... to have that economic model today.

Well, no, I appreciate that on the oil sand side. I was really thinking more about the targets to 2030, the reduction in methane, the decrease in freshwater usage. I appreciate 2050. I'm pretty sure I won't be here holding you to account then anyway.

Yeah, yeah. So on the methane reductions, You know what, the teams, our fuel operation teams have done a fabulous job in the field. We're using some of the latest technologies in terms of identifying leaks and opportunities of fugitive emissions to reduce it. So actually, yeah, in the end, we'll see more benefit because more natural gas will be sold. Obviously, some of the sites that... We feel we can consolidate economically and get that benefit. So, yeah, there is economic benefit to those. And the fresh water is the same. Obviously, the more water we recycle, it will be less energy and more efficient on the operations. So that's what the goals of the teams, and they're working to progress those opportunities. But they're all very economic and very complementary to our operating costs.

Okay, great. Thank you.

Yep. Your next question is from Mano Holthoff with TD Securities.

Good morning, everyone. I just have one on shareholder returns. You're clearly committed to a 50% free cash flow allocation of buybacks once the $15 billion of debt is achieved and That obviously precludes variable and special dividends, which are getting quite a bit of play in the U.S. Can you just remind us of how you think about the different shareholder return mechanisms philosophically and whether variable or special dividends could ever become a part of the conversation, or is that just too much of a stretch?

Yeah, I think, Menno, when we look at the asset base and the long life, low decline, predictable cash flow, it really supports that sustainable, you know, growing year after year type of dividend. So that today has been the focus. Of course, dividends and these, you know, allocations, returns to shareholders are board decisions. But that's really how we see the dividend. It just fits, you know, the way we've gone about it fits really well with our asset base. And, you know, returns to shareholders through share buybacks gives us that opportunity to return more value as we generate growing free cash flow.

And if you look at 2020, I mean, we were, you know, one of very few companies that grew our dividend and maintained the balance sheet. So, you know, the assets are very amenable to a predictable growing dividend.

Perfect. Thanks a lot.

There are no further questions. I'll turn the call back to Mr. Beaver.

Thank you very much, operator, and thank you to those that joined us today on the call. If you do have any questions, please don't hesitate to give us a follow-up. Thank you, and goodbye.

That concludes today's conference. You may now disconnect.