Jul 31, 2020
ExxonMobil XOM Q2 2020 Earnings Call Transcript
ExxonMobil (symbol XOM) reported Q2 2020 earnings on July 31. The company reported a loss of $1.1 billion, saying that oil demand “fell to levels we haven’t seen in nearly 20 years”. Read the full earnings conference call transcript.
Transcribe Your Own Content
Try Rev and save time transcribing, captioning, and subtitling.
Speaker 1: (00:00)
Good day, everyone. Welcome to this Exxon Mobil Corporation Second Quarter 2020 Earnings Call. Today’s conference is being recorded. At this time, I’d like to turn the call over to the Vice President of Investor Relations and Secretary, Mr. Stephen Littleton. Please go ahead, sir.
Stephen Littleton: (00:16)
Thank you. Good morning, everyone. Welcome to our second quarter earnings call. We appreciate your participation and continued interest in ExxonMobil. I am Stephen Littleton, Vice President of Investor Relations. Before getting started, I wanted to say that I hope all of you on the call, your families and colleagues, are safe in light of the challenges our world continues to face. Joining me today is ExxonMobil Senior Vice President, Neil Chapman, who oversees our Upstream business. After I cover the quarterly financial and operating results, Neil will provide his perspectives and provide an update on the steps we’re taking to navigate the current market environment and ensure we remain well positioned for the recovery. Following Neil’s remarks, I will be happy to address specifics on the quarterly reported results, while Neil will be available to take your questions on broader themes, including the corporation’s strategic priorities, progress on spending reductions, updates on major projects and views on market fundamentals. Our comments this morning will reference the slides available on the Investors section of our website. I would also like to draw your attention to the cautionary statement on Slide Two and the supplemental information at the end of this presentation. I’ll now highlight the developments since the first quarter of this year on the next slide.
Stephen Littleton: (01:41)
In the Upstream, liquids realizations fell by about 50% compared to the first quarter as impacts from the coronavirus rippled through the global economy, significantly reducing demand. In response to the unprecedented market conditions, production was curtailed by approximately 330, 000 oil equivalent barrels in the quarter. Despite considerable challenges, including global travel and supply chain disruptions, we were able to maintain strong operational performance in all of our businesses. We also progressed growth projects such as Guyana, with Phase I demonstrating nameplate production capacity, and we progressed Phase II FPSO topside integration in Singapore. In the Permian, the Delaware central processing and exporting facility started up, which enhances our integrated position in the Basin through collection and processing of production from our Delaware Basin assets and enables efficient, lower-cost delivery to Gulf Coast markets.
Stephen Littleton: (02:45)
In the Downstream, refining margins decreased from first quarter levels and were 50% below 10-year annual lows, reflecting the significant reduction in demand and the resulting impact of increased levels of product inventory. Refinery sparing was approximately 30% with reduced demand. However, utilization improved through the quarter as we saw early signs of recovery from the lows, including demand for road transportation fuels. Although bottom-of-cycle conditions persist in the chemical business, margins were sustained at first quarter levels, with lower realizations being offset by lower feedstock costs. While COVID-19 impacted demand in the chemical industry, the impact across our portfolio was moderated by resilient demand in the packaging and hygiene segments.
Stephen Littleton: (03:35)
At a corporate level, our people continue to support COVID-19 response efforts through our manufacturing operations and donations of critical products and resources, which Neil will highlight a bit later in the call. We also launched a collaboration with universities, environmental groups and other industry partners to find new and better ways to monitor and reduce methane emissions. The first of its kind effort called Project Astra is focused on developing an innovative sensor network in the Permian Basin to continuously monitor methane emissions across large areas to enable quick and efficient detection and repair of leaks, ultimately leading to lower emissions.
Stephen Littleton: (04:19)
Let’s move to Slide Four for an overview of second quarter results. The table on the left provides a view of second quarter results relative to the first quarter. Starting with first quarter 2020, the reported loss of $600 million included unfavorable identified items of $2.9 billion, driven mostly by non-cash inventory adjustments. Excluding these items, first quarter earnings were $2.3 billion. Second quarter results included a $1.9 billion non-cash benefit from inventory valuation, largely reversing the first quarter impact due to the improvement in commodity prices relative to the end of March and resulted in a second quarter U.S. GAAP loss of $1.1 billion. Excluding identified items, there was a $3 billion loss in the second quarter, down $5.3 billion from the first quarter driven by the effects of COVID-19, including the unprecedented decline in oil and product demand, resulting in significant declines in prices. These impacts were in line with the market factors that we previously communicated. Within the quarter, April marked a low point, with results improving through May and June. However, it’s worth noting refining margins remain very challenged, notably in North America with record high product inventories. Beyond the significant reduction in prices and margins, lower volumes in the quarter due to the demand impacts from the pandemic reduced earnings by $600 million. Lower operating expenses across all three of our businesses from reduced activity, lower overhead, logistics optimization and supply chain efficiencies improved earnings by $800 million. These efforts demonstrate the progress we’ve made towards our 15% cash OpEx savings target.
Stephen Littleton: (06:16)
Moving to Slide Five, Upstream earnings, excluding identified items, decreased by approximately $3 billion, largely driven by lower prices, with liquids realizations down 50% and natural gas realizations down 25% versus the first quarter. Foreign exchange and other impacts reduced earnings by $360 million. Volume impacts were driven by timing of scheduled maintenance activity and lower European seasonal gas demand. Expenses were lower in the quarter with savings related to efficiencies and work processes, reduced unconventional and exploration activity and market-related savings, including lower contractor rates and lower rates on materials and supplies. On the next slides, I will provide more details on volumes. Upstream volumes decreased by approximately 400,000 oil equivalent barrels per day compared to the first quarter. Due to the challenging market conditions, we curtail production in unconventional and heavy oil assets starting in April. Additional government-mandated reductions were implemented in May. As previously mentioned, natural gas demand was seasonally lower, primarily in Europe. Scheduled maintenance, notably in our LNG portfolio, also contributed to lower volumes. Compared to the second quarter 2019, Upstream volumes decreased by approximately 300,000 oil equivalent barrels per day. In addition to the factors I just referenced, volumes were lower due mainly to the divestment of the Norway non-operated assets at the end of 2019. It’s worth noting that half of the divestment impact was related to gas volumes. Finally, we saw continued liquids growth from our investments in the Permian, Abu Dhabi and Guyana, reflecting the continued value growth we are focused on.
Stephen Littleton: (08:11)
Moving to Downstream on Slide Eight, earnings, excluding identified items decreased approximately $2 billion relative to the first quarter. Lower margins and demand impacts driven by COVID-19 decreased earnings by nearly $2.6 billion, with refining capacity spared in line with significantly reduced demand. Included in the margin factor is the absence of first quarter’s favorable mark-to-market impact of $1.1 billion and an unfavorable impact of approximately $200 million in the second quarter. This period-to-period impact was driven by significant volatility in the prices of the underlying commodities. Our trading program is structured to maximize the value from our global asset base, leveraging our logistics and insights across the value chain. We are positioned to capture value as market disconnects occur, for example, by utilizing storage for crude and products from logistics capacity tightens. That said, trading and the use of financial derivatives to capture arbitrage opportunities can introduce additional volatility in our results due to the timing of recognizing open financial derivatives while not having the physical offset at the same time. Lower turnaround activity increased earnings by $190 million. Reduced expenses, including logistics efficiencies and lower contract rates, contributed another $220 million to the second quarter results.
Stephen Littleton: (09:45)
Moving to the next slide, I will discuss downstream results relative to second quarter 2019. Earnings, excluding identified items, decreased approximately $1.1 billion versus the second quarter of 2019. The drivers are similar to what I just discussed, absent the significant market-to-market effects associated with the swings in commodity prices. I would highlight the $0.5 billion contribution we saw year-over-year from lower turnaround activity and increased production of higher-value products as a result of the recent investments in our manufacturing facilities. Additionally, we continue to see the benefit of expense reductions and efficiencies discussed on the previous slide, which improved earnings by $ 340 million.
Stephen Littleton: (10:32)
Moving to the next slide, I will discuss Chemical results. Chemical earnings, excluding identified items, decreased by just over $100 million. The margin impact quarter-to-quarter was flat, reflecting similar trends in feedstock cost and product realizations. While we benefited from resilient demand in the packaging and hygiene segments, COVID-19 had a more significant impact on our durables in the automotive sector, resulting in overall reduced volumes impacting earnings by $170 million. Consistent with what we saw across the corporation, reduced expenses, including impacts from turnaround and maintenance efficiencies and supply chain savings, improved Chemical earnings by $110 million in the quarter.
Stephen Littleton: (11:20)
Turning to Slide 11, Chemical earnings, excluding identified items, increased by more than $150 million relative to the second quarter of 2019. While higher margins from lower fee costs improved earnings by $140 million, this is more than offset by lower volumes from COVID-19 impacts on demand. However, we saw dramatically lower expenses, improving earnings by nearly a quarter of a billion dollars, with drivers consistent with what we saw on the prior slide.
Stephen Littleton: (11:50)
The next slide highlights the strong progress we’ve made to date, reducing spend in response to the current market environment. Back in April, we announced that we will be reducing 2020 CapEx by 30% and cash operating expenses by 15%. Through the second quarter, we are on track to meet or exceed these targets. Cash operating costs in the second quarter were down about 15% relative to the first quarter, with reductions across all three of our businesses, as I previously mentioned. The cost reductions reflect decreased activity, maintenance and turnaround efficiencies, reduced contractor rates and lower structural costs from logistics optimization and supply chain efficiencies. As we optimize work processes, including how and where we perform work, we have identified structural opportunities that have lowered our costs. In terms of our capital spend, second quarter was down 25% versus the first quarter. We are pacing investment in the near term while prioritizing capital optionality that preserves long-term value. Additionally, we have optimized project execution plans to further reduce spend. Our short-cycle investments, particularly in the Permian, provide us with optionality as the market recovers. We want to be well positioned to capture the eventual upswing.
Stephen Littleton: (13:12)
Moving to Slide 13, let me highlight steps we have taken to improve liquidity and ensure the corporation is well positioned to manage the current market environment. During the quarter, we leveraged our access to capital markets by issuing approximately $15 billion in debt, including approximately $5 billion of euro-denominated bonds. This issuance enabled us to capture attractive euro bond rates and diversify our fixed income investor base. The corporation’s total liquidity has increased significantly since year-end 2019. As Neil will discuss in greater detail momentarily, we believe we now have sufficient capacity to weather the near-term market challenges and preserve our long-term growth plans and capital allocation priorities.
Stephen Littleton: (14:02)
Let’s turn to the next page for a look at the second quarter cash profile. Second quarter cash flow from operating activities was in line with our projections of the COVID-19 impacts. There was an increase in working capital in the quarter driven by a seasonal reduction in payables and a continued inventory build coming out of the first quarter associated with a steep reduction in demand. Gross debt increased approximately $10 billion in the quarter, reflecting the steps I just mentioned to increase liquidity in light of the current market uncertainty. As a result, we ended the quarter with $12.6 billion of cash.
Stephen Littleton: (14:41)
Turning to Slide 15, I will cover a few key items for consideration with regards to our outlook for the third quarter. In the upstream, economic production curtailments are expected to average 60,000 oil equivalent barrels as market conditions have continued to show improvement, and we’re forecasting an impact of 140,000 oil equivalent barrels with a full quarter of government-mandated curtailments in line with public announcements. In the Downstream, we anticipate scheduled maintenance to be down slightly from the second quarter. However, as we reflect on the current business environment, including the high inventory levels, we would expect margins to remain very weak. In Chemical, we anticipate demand improvement in key durable and automotive sectors, partly offset by higher feed costs. Scheduled maintenance is expected to be in line with the first quarter of this year. Corporate and financing expenses are expected to be about $800 million, and we expect continued spending reductions consistent with our announced targets. With that, I will now turn the call over to Neil.
Neil Chapman: (15:50)
Thanks, Stephen. It’s great to be on the call this morning. I hope that all of you joining us and your families are safe and healthy, and I want to extend the gratitude of everyone here at ExxonMobil to all of the men and women working on the front lines to fight the virus and to help those suffering from its effects. I’d also like to thank our employees for all that they are doing to support the response efforts globally.
Neil Chapman: (16:17)
As we indicated during the first quarter, we anticipated the COVID pandemic and related economic shutdowns would significantly impact the financial performance of companies across multiple sectors in the second quarter, and we’ve seen that reflected in the results announced to date. As Stephen just discussed, the same external factors were evident in our second quarter earnings and cash flows. However, there’s reason to be encouraged that we may have seen the trough in April when WTI hit a historic low point and then began to rebound as economic activity picked up and demand showed signs of increasing. By the end of the quarter, WTI had risen to around $40 per barrel, with Brent trading slightly above that, and oil prices have remained relatively stable at that level in recent weeks.
Neil Chapman: (17:11)
I’d like to begin with a few overarching comments on one of the most challenging quarters this industry has seen. We have acted quickly and decisively while preserving long-term value. The organization has responded with a level of commitment and professionalism that has been exceptional. We rapidly adjusted our plans and asked the organization to deliver on very aggressive new targets. They have delivered. Through all of the challenges this environment has presented, we have safely maintained the integrity and continuity of our operations, while also making the necessary adjustments to COVID-19 to provide a safe work environment for our workforce and support global response efforts. This success should not be underestimated. Essentially all of our global facilities, Upstream, Downstream and Chemical, have operated without interruption. You can imagine the challenge of maintaining a virus-free environment on offshore platforms and refineries, where our workforce live and work in close proximity. We’ve had to charge planes to move our rotating operating staff all over the globe without the availability of commercial planes. We’ve had to lease hotels in multiple cities to quarantine our folks before they start their 30-day rotations. Our organization’s ingenuity has been remarkable.
Neil Chapman: (18:45)
We’ve responded quickly to the rapidly changing price and margin environment by shutting in facilities when necessary and capturing value from the rapidly changing prices, leveraging our extensive supply chains around the world. I’m very pleased with the progress we’ve made reducing costs and pacing investments to adjust to the market conditions. As Stephen described, we set very aggressive operating and capital expense targets. The organization is exceeding those targets, which positions us very well for the rest of the year. We ended the quarter with more than $12.5 billion of cash, which is in line with the business needs. Given this level of liquidity, we don’t see a need to take on additional debt.
Neil Chapman: (19:33)
Before I dive into the business, I want to highlight some of the amazing work our people have done in response to the COVID pandemic. These efforts included reconfiguring manufacturing operations, optimizing processes and delivery systems, enabling us to increase production of essential chemicals that are critical to the world’s medical response, including isopropyl alcohol for hand sanitizer and specialty polypropylene for masks and medical garments. Our people have stepped up to contribute educational supplies to schools, fuel and PPE for first responders and financial support to food banks and many other related causes. If you haven’t already, I encourage you to visit our website to see all of the inspiring ways our employees have contributed during this time of need.
Neil Chapman: (20:26)
Now I’ll turn to what we’re seeing in the markets. Consistent with oil prices reaching historic lows, our own retail sales reflect a bottoming of transportation fuel demand in April, followed by some encouraging signs of recovery. The shape of the recovery varies by region, though the demand in Asia recently surpassed where it was a year ago. This data is from the International Energy Agency. What we saw was a historic demand contraction for transportation fuels with countries around the world impacted at nearly the same time, but we are seeing a recovery from the recent lows. Reflecting the improving demand trends we’re seeing, the IEA’s view of the next 18 months is similar to ours. They’re forecasting a rebound in road transportation fuels, with fourth quarter 2020 demand expected to be at similar levels to the fourth quarter of the prior year.
Neil Chapman: (21:24)
The recovery in jet fuel demand is likely to be much slower with by far the sharpest reduction in demand and the slowest recovery expected. As you would expect, the impact of lower demand was apparent in the second quarter, the refinery crude throughput, about 15% below 2019 levels. This resulted in pressure on margins, which Stephen discussed a few moments ago. Looking more broadly at total liquids demand, the second quarter was down about 20% year-on-year, but it’s important to note the actual loss of demand was not as severe as some had expected, considering the low end of the range …
Neil Chapman: (22:03)
Severe as some had expected, considering the low end of the range was about 30%. Simply put, the demand destruction in the second quarter was unprecedented in the history of modern oil markets. To put it in context, absolute demand fell to levels we haven’t seen in nearly 20 years. We’ve never seen a decline with this magnitude and pace before, even relative to the historic periods of demand volatility, following the global financial crisis and as far back as the 1970s oil and energy crisis. In response to this lower demand, we saw a similarly unprecedented reduction of supply in the second quarter, as OPEC plus was down approximately 11 million barrel per day in May and June. North American production shut-ins are estimated to have peaked at more than two million barrels per day. However, in line with the extraordinary drop we saw in demand, inventory levels increased to unprecedented levels, and we anticipate it will be well into 2021 before the overhang is cleared and we returned to pre pandemic levels.
Neil Chapman: (23:11)
As mentioned, clearly the industry has taken significant steps to reduce production. We have taken decisive action in this regard as well. The tailwind impacts in the quarter were about 330,000 oil equivalent barrels per day. Roughly two thirds of these volumes were economic entailments in unconventional and heavy oil. We brought the majority of production from our shorter cycle and conventional plays back online in July as market conditions recovered. For our heavy oil assets, we took advantage of the economic entailments to pull forward planned maintenance. At [inaudible 00:01:49], we completed a maintenance shutdown on line two, and it’s now back online. In the middle of July, we shut down line one for similar planned maintenance, and this is expected to return to service in later August. Looking ahead to the third quarter, we anticipate an impact of approximately 200,000 oil equivalent barrels per day from curtailments, with about 70% of those mandated by governments. Turning to Permian basin.
Neil Chapman: (24:15)
Second quarter production was nearly 300,000 oil equivalent barrels per day. That’s a 9% increase versus the second quarter of 2019. We continue to anticipate 2020 production will be about 345,000 oil equivalent barrels per day. It’s down just 15,000 barrels per day from what we discussed back in March, despite the curtailments and the sharp reduction in capital expenditure and still more than 70,000 barrels per day above the full year 2019. During the quarter, we started up the Delaware basin central processing and exporting facility, which we refer to as Cowboy. As I discussed in March, this is a key building block in our poker league major development. As we’ve discussed previously, the short cycle nature of our Permian assets also provides flexibility to pace development, reduce spend, and preserve cash in the current environment. We cut our rig count by about half, ending the quarter with 30 rigs in the Permian basin.
Neil Chapman: (25:21)
And we expect to cut that number by at least half again, by the end of this year. Our activities for the rest of the year will be focused on Poker Lake, where we will continue to leverage our development scale advantage and utilize the above surface investments that we have pursued in the last 18 months, including Cowboy. In light of the recent low price environment, we also pushed out the flow back of our largest to date cube development to the third quarter. This is the 27 well cube in the Midland basin that I referenced at our investor day. Again, this decision reflects our focus on making the appropriate decisions to maximize the value of each well and adapt as market conditions become more favorable, including optimize completion timing for our inventory of drilled, incomplete wells. In Guyana, Lisa phase one demonstrated production capacity of 120,000 barrels per day during the quarter.
Neil Chapman: (26:17)
The response to a mechanical issue that we experienced in May was slowed by logistical challenges of mobilizing technical experts and materials in country due to COVID restrictions. So these are close to being resolved and we expect to get back to full capacity with 100% gas injection in August. We’re still actively investing for the future in Guyana with four drilling rigs as of the end of June, with one on exploration and three on appraisal and project development drilling. Subsequent to the quarter end drilling at Yellow Tail two identified two additional high quality, hydrocarbon bearing reservoirs. One adjacent, and one below the Yellow Tail field. Lisa phase two remains on schedule for a 2022 startup. You can see the FPSO in the photo, which is currently in Singapore for topsides integration. We are continuing to work with the government on approval for the Pieara development plan. Without final resolution of the election result and signing in a new government there is a potential for delays to the schedule.
Neil Chapman: (27:24)
Having said that, it’s very clear that all parties in country understand the importance of progressing the developments quickly, given the significant benefits to all stakeholders, especially the citizens of Guyana. Let’s now turn to the progress we’re making on the aggressive cost reduction measures we put in place earlier this year, starting with capital expenditures. In April we reduced our plan for this year by 30%, $23 billion. We’re on pace to meet or exceed that target. In fact, our annualized run rate in the fourth quarter is expected to be around $19 billion and we expect to be lower still in 2021. Savings during the second quarter were primarily driven by short cycle unconventional activity. But I should note that we’re also adjusting the pace of other investments in all of our businesses. As we’ve previously mentioned, we continue to take a very thoughtful and comprehensive approach to these cost reductions, in partnership with our contractors partners and governments. You will hear me say several times this morning, the importance of addressing the short term market challenges while conserving cash and preserving longterm value and future optionality. This helps us ensure that while investments may be deferred in some areas, the opportunities remain. Given the continued uncertainty and volatility, we will continue to adjust CapEx reductions as needed while also being mindful that the pullback we’re seeing across the industry today could very well lay the foundation for supply challenges in the future. And we want to make sure we’re positioned to capture the eventual upswing. In addition to our targeted near term CapEx deductions, we also laid out plans to reduce cash operating expenses by 15% in 2020. Again, we are delivering. We’re ahead of pace to achieve that target with savings coming from a wide range of activities, including lower unconventional activity, optimizing supply chains, lower material and service costs and work process improvements to reduce support and overhead costs.
Neil Chapman: (29:38)
These are just a few examples. Our savings are widespread across the corporation. More importantly, we’re doing it without compromising safety or operational integrity. Over the past few years, we underwent a reorganization of our businesses from what were primarily functional organization structures to aligning along value chains. These reorganizations reduce the senior leadership structure and associated overhead and improve the line of sight across the value chains to better drive performance from our assets. At our Investor Day in March, we discussed how this organization has provided a new lens on the business to identify and improve ways to drive further efficiencies. You might recall, Darren made the point that our plan for this year included reducing our operating costs on our base assets by more than $1 billion. And he said that we would do even better in 2021. So we came into the current environment in a good position to respond quickly with confidence that we will meet or exceed our cost reduction targets for 2020. Looking ahead to 2021, we see significant potential for additional reductions based on identification of further longterm, structural efficiencies, reduced activity levels, and an evaluation of our workforce requirements, including the potential for further reductions in overhead and management positions.
Neil Chapman: (31:13)
Our plan is to continue looking at reductions business by business and country by country. Consistent with our annual budgeting process, we’re working through these plans and we would expect to have them finalized during the second half of the year and share them with you early next year. Let me now address capital allocation. Our longterm capital allocation priorities remain unchanged. In a depletion commodity business, you have to invest in a creative advantage projects to sustain a strong foundation to generate cash flows into the future. In a capital intensive cyclical business, such as ours, it is critically important to maintain a strong balance sheet. This enables us to sustain through the commodity price cycle and be flexible when opportunities present themselves. It has been a strength of this corporation for decades, and it is an advantage that we will maintain. Finally, we have a long history of providing a reliable and growing dividend.
Neil Chapman: (32:16)
A large portion of our shareholder base has come to view that dividend as a source of stability in their income. And we take that very seriously. While we manage our capital allocation priorities over the longterm, we also recognize the need to balance in the near term to respond to market conditions. In response to the unprecedented environment that we find ourselves in, we’ve taken decisive action in 2020. To recap what we’ve done so far this year, we’ve reduced short term capital spending by more than 30%, we’re on pace to reduce cash operating expenses by more than 15%, we’ve increased debt to a level we feel as appropriate to provide liquidity given market uncertainties, and we will hold it at that level. And we’re continuing to pay a reliable dividend.
Neil Chapman: (33:08)
Given the ongoing uncertainty in the business environment, we’re developing plans that will enable us to maintain our capital allocation priorities over the near term. These plans contemplate a price environment that is consistent with a range of third party estimates and in line with the shape of the recovery that I discussed moments ago. The plans will include further reducing operating expenses and identifying additional opportunities to efficiently defer more CapEx. Doing so will enable us to maintain the dividend and hold debt at its current level. Of course, this is a volatile market and we can’t know with certainty how the market will evolve from here. There are simply too many unknowns. While we’re developing plans based on what we and other third parties can reasonably expect to happen, we have to maintain a certain degree of flexibility to be able to respond to potential improvement or further degradation.
Neil Chapman: (34:06)
Before we opened up the call for questions, I want to reemphasize a few key points. Our people continue to demonstrate a commitment to safety and operational integrity and continuity in an incredibly challenging environment. Our company continues to benefit from the integration advantages we build across the value chain. We remain focused on driving down costs and pacing investments to manage the near term market challenges. We’ve maintained financial capacity in line with our business needs and the market environment. We will continue to be there for the communities and frontline workers who depend on the products and support we can provide to combat the ongoing pandemic. I am confident in our organization and our plans. We will overcome the challenges of the current environment, just as we’ve overcome many challenges in the past. Thank you and we look forward to taking your questions.
Speaker 2: (35:04)
Thank you for your comments. Thank you.
Speaker 2: (35:09)
We’ll now be more than happy to take any questions you might have.
Speaker 3: (35:14)
Thank you, Mr. Littleton, and Mr. Chapman. The questions and answer session will be conducted electronically. If you’d like to ask a question, please do so by pressing the star key, followed by the digit one on your touch tone telephone. We request that you limit your questions to one initial with one followup so that we may take as many questions as possible. If you’re using a speakerphone, please make sure that your mute function is turned off to allow your signal to reach our equipment. Additionally, please lift your handset before asking your question. We’ll proceed in the order that you signal us and we’ll take as many questions as time permits. Once again, please press star one on your touch tone telephone to ask a question and we’ll take our first question from Jeanine White with Barclay’s.
Jeanine White: (35:55)
Hi, good morning everyone.
Speaker 3: (35:59)
Jeanine White: (36:00)
My first question is on the debt and in terms of the commentary that Exxon doesn’t need to take on any additional debt, this implies a price and CapEx assumption. Can you provide a little more color on what your price assumption is and what lanes of dimension area to do you look at compared to what you laid out in the presentation, which was really helpful. Just wondering also if the message is that Exxon will adjust CapEx back to the price environment, regardless of what the impact on production is in order to just hold the line on that debt.
Neil Chapman: (36:33)
Yeah. Good morning, Janine. This is Neil. Thanks for joining the call. Good to hear from you. Of course, as you are aware in the response to this environment, which clearly has been unprecedented, we’ve never seen the market demand crash so far, so deep. We’ve never seen and margins crash so much. And that’s why having a strong balance sheet is so important. And I would tell you, that’s why the financial discipline of this corporation over many, many decades has been so critical. It means you can weather the big storms. It means you can weather the large scale disruptions. And of course it also means you can reward the loyalty of our shareholders by sticking with them when the business recovers and sticking with the plans we have in place to protect this balance sheet and maintain our dividend. As we’ve just been discussing or describing, we took really, really decisive steps for this year. So the short term capital spending reduction of 30% or 15% in operating expenses, this is very much in line with what we saw in our April earnings call. You will recall that Darren laid out our plans then.
Neil Chapman: (37:44)
What we said we needed to do at that time, we’ve done. The results are on track and are in line with our expectations. So we set out the plans for this year with these reductions. We’re now developing plans that are going to enable us to maintain our capital allocation priorities over the near term. And these plans contemplate a price environment that’s generally consistent with third parties. Of course, we’ve seen the third party assessments of the price environment going forward converge and we’re in line with those. Our plans to maintain our debt at the current levels and maintain our dividend include further reductions in operating expenses. And we’re working hard to identify additional opportunities. To what I always describe as efficiently defer more CapEx and that preserves the optionality and the future value, but responds to these short term needs.
Jeanine White: (38:42)
Okay, great. That’s really helpful. Thank you very much. My follow up is just on those spreader or CapEx reductions that you’ve mentioned, if oil prices remain modest and you’re looking to potential delay from our projects, you’ve mentioned in the past there’s always a cost associated with delaying this project. And so can you just address that and what kind of projects you might see might be opportunities to defer? I know the run rate of 19 billion that you’re talking about is significantly lower than the 2020 budget. On the flip side of things, given the project backlog, at what point does MNA become a more attractive option instead of delaying things as a means to kind of grow the medium and longterm cash flow. Thank you.
Neil Chapman: (39:27)
Yeah. Thanks Jeanine. Well, we remain committed to progressing the structural improvements to our earnings and the cash flow that we’ve laid out for the last three years, but we have to be more selective in pacing those investments in light of the market environment. And of course, and as we’ve described, and actually Darren described as well in April, we’ve completed a thorough review of all of our ongoing investments and our ongoing investment opportunities, but in our business that means you’ve got to work with the resource owners, you’ve got to work with the partners, you’ve got to work with the stakeholders. We’ve got to identify areas where we can defer spending, but conserve cash in the near term. And of course preserve that long term value. What we have done and I think we’ve done really successfully, is we’ve identified market efficiencies. We’ve identified project synergies that will offset the cost of these deferrals, but there will be impacts.
Neil Chapman: (40:23)
I mean, that’s for sure. And there will be impact mainly in timing and that’s to the earnings and cash flow potential that we’ve previously communicated. So it’s clear, I think from our comments and our actions in the short term, we’ll defend the balance sheet and we’ll protect the dividend by taking short term postponements in capital investments. In terms of what we will do next year, of course we’re working through that now and that’s part of our annual planning process. And we’re working through that now. And as you’re well aware, our plan process concludes with a review with our board of directors in November. That will be the same this year as it is every year. And when we have clarity on what that capital spend will be next year, of course, we will communicate it to you. As I mentioned in my comments, my expectation is our capital spending next year will be lower than the fourth quarter run rate.
Neil Chapman: (41:19)
In terms of MNA and could that provide a different option to us, I mean, Janine of course, we’re looking at that all the time. We’re looking all the time and if the right opportunity comes up, then we may elect to move on that. But what I would say is, and I said this before, and I certainly said on the Investor Day, we have, I would say, the very richest set of competitive investment opportunities within this company already. I mean, I don’t think there’s a company out there that can compete with that. And so there’s no need for us to do an MNA, we don’t need to do that. We have very, very attractive investments to make, but we always look at that option.
Jeanine White: (42:03)
Neil Chapman: (42:07)
Speaker 3: (42:10)
Next question comes from the line of John Rigby with UBS. Morning John. And John, your line may be muted.
Neil Chapman: (42:29)
No, we still can’t hear you, John.
Speaker 3: (42:33)
Okay. We’ll move on for now to Doug Leggett with Bank of America.
Doug Leggett: (42:39)
Thank you. Can you hear me okay?
Neil Chapman: (42:40)
Sure can Doug.
Doug Leggett: (42:42)
Good morning and good to hear you. So a lot of questions. I’ll stick with Neil. You talked about the run rate CapEx being 19 billion in the second half and below that in 2021, and you are still drawing the Permian and you’re still executing Guyana. Can you then confirm that that would still include growth capital and what I’m trying to get to is, some idea of what Exxon Mobile sustaining capitalism, in other words, X growth, if you can help me with that.
Neil Chapman: (43:18)
Yeah. Thanks Doug. Just to clarify one point, our run rate of 19 is in the fourth quarter, not the second half, just so you’re aware. And what I said, I expect, Doug, it will be lower. We will fund all the Guyana opportunities as they come forward. Of course, as we look at our capital spend, we’re looking hard at the priorities on them and Guyana, we will continue to fund. And you’re well aware that Lisa two is in construction. I’m confident we’ll move on Pieara as well. In terms of the Permian, they’re one of the great attractions of short cycle, as you can take that capital off quickly. And of course you can put it back on pretty quickly as well.
Plus you can put it back on pretty quickly as well. Our current planning is that we will continue to reduce the number of rigs we have out in the Permian through the second half of this year. I think we are, if I remember the numbers, about 30 rigs in the Permian at the end of the second quarter. I would anticipate we’ll be in the range of 15, maybe 10 to 15 at the end of the year. And that really is just a short term to manage our current capital planning.
Those rigs that we have in the Permian will be focused on that Poker Lake development. So what we’re doing is we’re concentrating our developments in the Permian in that core activity in Poker Lake that we’ve talked about for the last two times, the last two investor days.
I would tell you, in terms of ongoing sustaining capital, I’m always reluctant to our business to put a number to that because as your portfolio changes, and as you make divestments, it’s not a number to lock in. And I’m really, really reluctant to put a number on that. I would tell you it’s somewhat easier in the chemicals and downstream businesses. I think that order of magnitude on sustaining capital in those businesses will be in the two to $4 billion range. But I think in the upstream, it’s more difficult to quantify in that way.
I understand this quickly, and I appreciate you explaining the answer. Gosh, I’m going to go to Guyana, if I may, on my second question.
You used an interesting term of phrase: there is a potential for a delay. And if I preface my question like this, our understanding is that the Piara hole is well ahead of schedule. I know that [inaudible 00:45:51] right now and [inaudible 00:45:52]. My understanding is also that Bay Phase has not yet finished its review of the development. And although you do not yet have a government, everything seemed to be ahead of schedule. So what exactly are you signaling on Piara in terms of the risk or the potential for delay?
Well, Doug, it’s really very simple. Everything we and the partners can do to progress Piara unscheduled, we are doing, and we’ve done. I’ve said to our organization many times, we need to be ready to move as soon as the government is ready. And we are ready, we’re ready to FID this project, but we need an approved development plan. And that approved development plan needs to come from the government. And all the work with Bay Phase and on the development plan, that’s been worked for a long, long time.
Of course, we’re waiting for a resolution like everybody else of the election. I think you’re very familiar with what’s happened down there. There was a vote, there was a recount, and then there’s been a series of legal actions that have taken place since that time. What we know is that all parties in Guyana want to progress this development. Of course, we’re in regular contact with both president Granger and the APNU AFC Coalition. And we’re also in discussions with the PPP and Jeff Dayo and [inaudible 00:47:13].
What we continue to stress to the government is that if the project does get delayed it’s a loss of value to the country. And they understand that. It’s very, very clear. The government understands that. It’s very, very clear. The Ministry of Energy understands that. It’s very important that we get this development plan so that we can FID in the September timeframe. There are weather conditions that if you miss a certain window it could result in delay of some months. And that’s what we’re trying to work towards. I’m confident this will get resolved, but Doug, we need that approval of the development plan and that’s what governments have to do. And obviously we’ll work with them. As I said, we’re ready to go.
Thanks, Neal. And thanks for the [inaudible 00:48:02] on the dividend.
Yeah. Yeah. And I appreciate it. Good to hear from you, Doug.
Speaker 4: (48:09)
All right. Next question comes from the line of Neal Meda with Goldman Sachs.
Neal Meda: (48:14)
Thank you, Steven. Thank you, Neal. The first question I had was around the dividend, and I think Neal, your comments there was, this is an imperative for you guys to defend. Can you just talk about the business logic and the financial logic behind defending the dividend? Especially in light of some of the dividend reductions we’ve seen and are likely to be upcoming from your competitors.
Yeah. We see it this way, and Neal tell you, our capital allocation priorities, as I said, in my prepared comments, they’re unchanged. I don’t think you’d expect anything different. I always see the three legs of a stool. It’s a commodity business so you’ve got to invest in advantage projects. You’ve got to invest in creative projects. That’s the way to sustain a strong foundation and to generate future cash flows. But of course the business is cyclical. We know that. It’s volatile. We all know that. That’s the norm, and therefore it’s important to maintain the strong balance sheet. And that’s what we’ve done for years. It enables us to sustain through the commodity cycle. It enabled us to work through this quarter. And that’s really, really important.
But third, we have a long history in this corporation of providing this reliable. And I would tell you, and as you know, growing dividends for 37 years, a large portion of our shareholder base, Steven may correct me, but I think something like 70% of our shareholder base are retail investors.
And that investor sets come to view that dividend as a source of stability in their income. And that’s something we take really, really seriously. So we manage this capital allocation priorities over a long term, but obviously it’s a balance. And obviously we recognize the need to balance in the near term to respond to what we’ve seen in these market conditions and market environment. And that’s why we’ve had the cuts in CapEx and OPEX. And that’s why we took on more debt in the last four months to a level that we feel is appropriate to provide liquidity given the uncertainties of the market.
But as I said, we don’t plan to take on any more debt. We’re now developing plans that belabors to maintain those capital allocation priorities over the near term. And that includes sustaining the dividend. Our plans contemplate a price environment that’s consistent with third parties. Of course, we look at sensitivities on the upside and the downside of that. We’re aware of what those will be. That is why we’re moving on further reduction of operating expenses and further short term reductions in capital expenditure. That will enable us to maintain the dividend. And that will enable us to hold our debt to current levels.
Now Neal, you’re well aware, we can’t know with certainty how the market will evolve from the edit. There’s too many unknowns, of course. So you have to maintain a degree of flexibility to be able to respond should the recovery not play out as expected. We feel very confident that we will be able to maintain that level of debt and maintain that dividend certainly for the coming year or months.
Neal Meda: (51:30)
Great. I’m sorry to keep on going back to the capital spending question, but I did think that is an incremental point of disclosure. So I just want to clarify some things here. Neal, are you saying that at the end of the year, your fourth quarter, annualized headline CapEx, not cash CapEx, will be $19 billion; and then in 2021 you anticipate you will be below that or else equal right now? And then can you just talk about the buckets where you could see some downside relative to the plan that you had outlined?
Yeah. Well, you are correct. That is what I said. In the fourth quarter we expect to be at an annual running rate of $19 billion. And what I said was, I expect, I anticipate we’ll be lower than that $19 billion in 2021. Of course, we have an annual plan process. That’s the way we work in this company. And we ultimately review that plan with our board of directors in November, and that will be finalized. That’s why I’m always saying, I expect we will do that. We will finalize the plan ultimately with the directors. And we’ll communicate that to you at that time.
I think in terms of where we’re taking those cuts, clearly the short cycle in the unconventional space is a way you can turn on capital and turn off capital relatively quickly. So the quickest cuts and the largest cuts we’ve made as we’ve discussed has been in the unconventional space, not just in the Permian, Neal, I tell you it is across all the unconventional space, and that will continue.
In the downstream and chemical projects it’s really a question of deferral. So we’re not stopping any of these projects, we’re deferring them, we’re postponing them. We’re working with our partners and we’re working with EPC contractors, and we’re working with local authorities. And that is why we’ve not been specific at this stage which project we’re differing over what period and when. When we have clarity with all of our partners, of course we will share that with you.
Neal Meda: (53:40)
Thanks, Neal. Thank, Steve.
Speaker 4: (53:46)
Next question comes from the lines of Doug Terreson with Evercore ISI.
Doug Terreson: (53:49)
Good morning, everybody.
Doug Terreson: (53:53)
Neal, economic value editor EVA for Exxon Mobile, and really every super major peer has declined steadily during the past decade or so, even though we’ve had a range of commodity prices and margins. And we’re now seeing the stock of the super majors falling to three and four decade lows versus SP 500. And on this point, one read could be that companies are investing cyclically or countercyclically, which I think is your all’s view despite secular deteriorating, or deterioration in competitive conditions. That is a decline in value creation that we’ve seen.
Doug Terreson: (54:29)
So two questions. First question is, how do you think about the secular slash cyclical risk part and the implications for spending? And then second, with Exxon Mobile stock at a 40 year low versus SP 500, why wouldn’t this argue for additional transformation of the company’s business structure, financial metrics, executive pay incentives, or whatever you think is important? Or do you think that the current plan is sufficient and it will eventually accomplish the objective? So what’s the market missing here?
We could discuss this for a long time, Doug. So I’ll try and be succinct. Look, in terms of how do we think about this business, we don’t think the long term has changed. It is a cyclical business. The fundamentals have not changed. The population will continue to grow. Economies will continue to grow. This relationship between societal progress, or you can describe it as human development, and energy consumption is absolutely clear. And the demand for energy by all third parties is going to be up 25% by 2040. We don’t see that’s changed.
In our business, of course, which is a depletion business, it’s not just a question of the growth in demand. It’s the depletion as well, which as you know, demand for crude oil. And again, I apologize, I don’t have these numbers exactly right. It’s about 0.7% annual growth and gas is probably 1.3, but the depletion is about 6%. So there is a need for hydrocarbons to come into the market and people to invest in hydrocarbons to meet that energy demand. And the winner will be the company with the strongest portfolio and the company with the strongest operating results. And that’s what we’ve been discussing at our last, however many, three investor meetings. And of course we’ve talked about, I’ll be very, very quick, we got the strongest set of development opportunities in the upstream, and we’ve got one of the most aggressive divestment programs and we’re driving costs out of the business. And the downstream, we’re not focused on growing fuels. We’re focused on upgrading fuels basically to distill it with diesel jet fuel and base stocks to meet that market demand and then causing chemical demand, which is growing fast, is driven by this growth in middle class. And we feel very well positioned in that business. I don’t see anything changing. There’s no evidence of anything is changing to any of that. I mean, that is for sure.
In terms of what do we need to do, and should we be doing more? I would tell you, Doug, that’s what we’re focused on. You only win in this commodity business if you have the lowest cost structure. Driving cost out of your business and upgrading your portfolio is what this business is all about. In terms of some of the comments around executive compensation, and in terms of workforce reduction, of course we’re looking at every element of that, as you would imagine when we go through a quarter like that, but I would tell you, we were already looking at all of this. And we started that process as we reorganized this company back in 2018 and 2019 with our big changes in organization structure in both our upstream and downstream. So I would tell you, in my opinion, we’re looking for structural efficiencies to improve this portfolio, to be the most competitive in an industry and in a business where we believe the longterm fundamentals are not changed and we don’t see any evidence that they’ve changed at this stage.
Neal, if you don’t mind I’d add. As we did the restructuring on the two businesses along the value chain construct, what we’re able to really identify as the overall cost of delivery of our products. And we’re identifying efficiencies across that entire value chain at a rate far higher than we really anticipated. And that’s where we’re going to start to see additional efficiencies going forward.
Yeah, Steven’s right, Doug. I will tell you that this evaluation that we’re going through is part of this year’s plan to set up our cost structure for future years, 21 and beyond. We are looking at very significant efficiencies and lower operating expenses. And I know you’re going to ask me, okay, what is the number? That is part of our planning process that we’ll share that with you at the end of it.
Doug Terreson: (59:02)
You know what I’m going to say.
But as I said in my comments, we do see the potential for further workforce reductions, including overhead and management positions. But we’ll look at that reductions by function, by business, by country. And that’ll be the basis. We will conclude those plans during the summer months and we’ll review that with the board in November.
Doug Terreson: (59:25)
Okay. So it sounds like we’ll hear an updated plan for potential or normalized earnings that you’ve provided in the past maybe next spring. Is that a good way to-
Yeah, that would be our intent. Yeah, exactly right. Exactly right.
Doug Terreson: (59:36)
Okay. Thanks a lot guys.
Sure. I appreciate it. Thanks, Doug.
Speaker 4: (59:42)
Next we’ll go to Roger Reed with Wells Fargo.
Roger Reed: (59:47)
Thank you. Good morning. Hopefully you can hear me?
Good morning, Roger.
Good morning, Roger.
Roger Reed: (59:52)
Okay, great. Great morning, Steven. Good morning, Neal. I’d like to maybe come at the CapEx question a little different way. Bear with me a second. As we think about what happened in the post 2014 CapEx cuts we saw a tremendous amount of improvement in productivity and efficiency and cost reductions just from your contractor subcontractor universe. Doesn’t look like there’s the same level of cost cuts to come out of that particular part. So as I think about a CapEx cut from the roughly 30 billion to the sub 20 billion range… You’ve mentioned deferrals, but are we going to see a more significant impact on whether it’s Exxon or the industry in terms of the ability to bring new oil and gas projects to market as maybe the main result here? I guess what I’m trying to think of is… Is this one going to have… This wouldn’t be your downturn and have a bigger impact on the industry is deliverability. You touched on that on the intro. I’m just interested in getting your thoughts on that.
Yeah. When you look across the industry, and we read the same reports that you do, and there’s been a dramatic cutback in our industry on capital expenditure. And history says there is a result of that. This is a depletion business. And when we all know what happens when you don’t invest in this business. It certainly suggests that will be the case this time around, but obviously I can only really talk about what we are doing and why… We’re taking these short term steps while preserving the longterm value. That is our objective. I would tell you that we are working very hard with the contractors, the material suppliers on every angle to drive further efficiencies and costs out.
The contracting industry is hungry because there’s been so much CapEx taken out of the business and people are suspended and postponed so many projects. So we’re working very, very hard. I have to tell you, in the downstream chemicals and upstream, I am… Well, first of all, I’m really pleased how well BBC contractors are working with us. It illustrates the great partnership we have with them. And jointly, we’re taking efficiencies and we’re offsetting the cost of these deferrals with increased efficiencies. That’s what I am seeing. That’s what we’re seeing in the business.
In terms of ability… Where the industry stops investing, will that impact the longterm of the ability to step up and reinvest again? There’s always that chance, but experience in a commodity business suggests that when the demand is there the market will deliver. I don’t see any difference here. I am very optimistic, though. So as a result of not just the oil crash in 1516, but what we’ve seen today, will fundamentally push this industry to do things more efficiently and take structural costs out of construction in a way that we have not previously seen. I hope that answers your question, Roger.
Roger Reed: (01:03:06)
Okay. [crosstalk 01:03:07] I think so. I mean, it’s always amazing to me just how much productivity and efficiency comes out of the industry, whichever the cycle, but especially in these down cycle moments.
Yeah. And I would tell you, as a business owner, Roger, it’s unbelievably frustrating, right? Because we should pay these efficiencies in the base case. But I agree with you, when times get like this then it’s extraordinary how the industry can find opportunities to do things more efficiently and take more costs out. Sorry, I interrupted your second question.
Roger Reed: (01:03:40)
No, that’s quite all right. Second question, shifting gears a little bit back to Guyana that Doug mentioned earlier. Between your partner having their call and his call today, in a nearby country there was another discovery in the deeper zones. The partner talked about some of the deeper zones. I was just wondering, how are you looking at that opportunity and how that fits within the greater than 8 billion of discovered resource so far? Where does it fit in the overall package? Would it be able to really tell you about that and some of the other opportunities there?
Yeah. I think you’re probably aware, our latest appraisal well, which was on a prospect we call Yellow Tail. We discovered two, I would tell you, additional high quality hydrocarbon bearing reservoirs. It’s very positive for us. And it’s very positive for the country and our partners. One was adjacent to Yellow Tail, and one was below Yellow Tail. So that further gives us confidence. It’s more learnings in terms of the potential at lower depths or deeper depths.
We’re now on a prospect called Red Tail. I would anticipate we’ll get some initial results in August on Red Tail. We’re going to move into the [Kater 01:05:01] block in August on a prospect called [Tanajer 00:01:05:04]. And of course subsequent to that we’ve got other exploration prospects that we’re drilling up in later this year. One in [Hassell One 01:05:15], and one in [Bulletwood 01:05:17], which is on the [K&J Block 00:01:05:18].
And my memory is correct those are what we’re doing. In terms of Suriname I think you’re aware we’re in block 59 down there, and we’re in block 52 with our partner, [inaudible 00:21:28]. We’re looking to drill a well in block 52 with our partner potentially in the fourth quarter of this year. I think the learnings and the understanding of the whole resource base in that offshore area, Suriname and Guyana, the more we find and the more we drill the more we understand about that whole prospect. But I would tell you that everything we’ve seen this year is consistent with what we’ve been talking about and-
… consistent with what we’ve been talking about, and we are very encouraged and very excited by the prospects going forward.
Speaker 5: (01:06:10)
Great. Thank you.
Of course. Thank you, [inaudible 01:06:15].
Speaker 6: (01:06:16)
Next, we’ll go to Sam Margolin with Wolfe Research.
Sam Margolin: (01:06:20)
Hello. Good morning.
Good morning, Sam.
Speaker 7: (01:06:23)
Good morning, Sam.
Sam Margolin: (01:06:25)
So to belabor the CapEx topic, but something that I think we landed on that’s pretty important, especially for investors. In the past, the process of budgeting CapEx was never explicitly tied to your expected sources of cash, and actually, as a matter of fact, the management committee would make it very clear that they were completely decoupled all the time and that just wasn’t the right way to run the business. And so do you think it’s a fair interpretation of your comments to say that there’s a real fundamental change in the way [inaudible 01:07:07] and that the source of cash including disposals and other non-operating factors are now a prominent part of that process, and we should think about it that way, or is this just a unique circumstance to the moment?
No, I don’t think it’s a fair way of characterizing it. I mean, in the short term, we have elected to do the following. We’ve elected to take no more debt on because we want to protect the strength of our balance sheet. We want to and we feel a great commitment to our dividend, and so what other knob do you turn when you’re in that situation? It’s capital expenditure. I see this as a short-term reduction in capital expenditure to manage the current situation. We retain a very competitive balance sheet, and you know that. You’ve seen this. It’s very competitive versus our peers, and we want to protect that, and so we’re doing that by taking shortcuts and expenses. It doesn’t change our fundamental belief that you need a strong balance sheet and you need to invest in the most attractive prospects, the most competitive prospects that are out there. So again, Sam, I don’t think it’s a fundamental change. I think it’s a response to the short-term environment.
Sam Margolin: (01:08:18)
Okay. And I apologize for belaboring that. I just wanted to clarify.
Oh, that’s fine.
Sam Margolin: (01:08:24)
On a related note, within this process of high grading for the near term, the focus seems to be on Permian, and it seems like the LNG projects may have fallen [inaudible 01:08:37] LNG sort of tied to some other goals for the company [inaudible 01:08:46]?
Yeah. Sam, we kind of lost you there, so I’m going to try and interpret what I heard. It was around LNG and the LNG projects, and you’re aware that we have two significant opportunities in Mozambique and in Papua New Guinea. I think we’re continuing in Papua New Guinea to work with the government on the P’nyang fiscals, and that process is ongoing. We’re continuing to work with our partners in Mozambique, both the government and our partners on the timing. I think consistent with what you see in our capital spending and consistent with what you see across the industry, there could be a time component in terms of a delay. You will recall that both those two projects, even in 2018, we were talking about them coming online in the 2025 type of period. There is a chance that will slip a few years or a little bit of time beyond that. Yeah. Sorry, Sam, we lost it. If that wasn’t the question you were looking for, that’s what I heard.
Sam Margolin: (01:09:54)
No, I was going to ask if you could tie to in some of the ESG efforts as well. But if I have bad connection, I’ll leave it there and ask Stephen later. Thanks a lot. Bye.
Speaker 7: (01:10:03)
Speaker 6: (01:10:08)
All right. Next, we’ll go to Phil Gresh with J.P. Morgan.
Phil Gresh: (01:10:12)
Hi, good morning. I guess I’m going to ask another follow-up, I suppose, on this topic. But as we look at the current cash balances for the company and your CapEx plans, is there a minimum level of cash that you’re, I guess, basing your commentary on that you would not plan to be adding additional debt, and is there anything in there or inorganically and plan around asset sales? Or is that commentary completely organic in nature? I guess the bigger picture question is, you’re talking a lot about efficiency improvements and lowering costs, so structurally, the $30 billion to $35 billion in CapEx you’ve talked about, is that something that through efficiency gains and things you believe actually would be lower in the future?
Yes. Let me try and address them in order. Asset sales, I mean, look, it’s not the best environment for selling assets, but I can assure you that we are in the market with multiple assets, and we’re progressing asset sales. Whether they will finalize or come to fruition, time will tell, but I think it all depends on what you’re selling, what market, what location, what’s the age of the asset, et cetera, and so we are extremely active in that space. But I never like to try and predict what will happen in the future of that because it depends on both the buyer and the seller. So but we’re still progressing.
In terms of cost savings, as I mentioned earlier on and how that impacts CapEx, I’m optimistic that when times get really tough for everybody in that supply chain of project development and project execution, you identify and drive new efficiencies. So you would hope that they can be retained, and you would hope and we certainly plan that we’ll benefit from those in the long term. Will it change our capital expenditure from $33 billion, which was our original plan for this year, down to $23 million just through savings? I think that’s probably a little bit optimistic, frankly, but we do see savings coming out, and we do see savings coming for the long term.
In terms of the cash balance, what we did was we took on more long-term debt over the last four months at what we regard is attractive or certainly relatively attractive prices, but that was to provide more flexibility during this period. When you’re in a volatile period, higher cash is what we wanted to do, and of course, it provides the optionality to reduce short- term debt. But that’s all part of our debt management, cash management, capital allocation process.
Speaker 7: (01:13:05)
I guess, Neil, I’d also add, currently, Phil, we have a pretty high cash level given the amount of uncertainty that’s out in the market, but if you go back in time, we’ve historically carried a cash balance in the $5 billion or lower. And so right now, obviously, we’re in an unprecedented time, we thought it was appropriate. We had the appropriate level of liquidity to manage us through the next couple of quarters just to make sure we see how the recovery is going to respond, but I look back on our history, usually, that cash balance is substantially lower.
Phil Gresh: (01:13:39)
Okay, thank you. Follow-up question. I suppose it’s semi-related to what Doug Leggate was asking about with respect to sustaining capital. It’s just more specific to the Permian. As we look at the exit rate that you’re talking about for the rig count and implicitly for capital spending, I think your guidance for this year of 345,000 on production would obviously imply something a bit higher than that as an exit. But I guess with this $19 billion or less of spending, should that imply to us that you would let Permian production decline in 2021, or do you feel that there are levers available to you that that would not be embedded in that plan?
Yeah. I would tell you let’s talk about Permian this year first. Our outlook for this year is pretty close to what I said at Investor Day. I think it’s, again, they’ll correct me here, but I think it’s 345,000 KBD, and so that’s about just 15,000 below, and that really reflects, because of the way we are developing the Permian with these large-scale developments and large cube developments. The capital you invest last year has a material impact on the results this year, and so that’s why it’s only a 15,000 KBD reduction.
In terms of the following year, we haven’t finalized those plans yet. Of course, if there’s no investment, these wells decline rapidly. But you’re aware that we have a considerable number of DUCs sitting out there. You’ll also be aware, it’s a much higher cost of frac than it is to drill, and that’s really, really important, so just looking at drilling rigs alone doesn’t tell you the full story. I don’t anticipate that our volumes will reduce next year. We’ll finalize that through the plan process. We’ll finalize that with our Board in November, and of course, we’ll share that with you at the Investor Day in the first quarter next year.
Speaker 7: (01:15:41)
And Neil, if you don’t mind, I’ll add, I think, Phil, it will also depend on what’s the business environment look like, and that’s the beauty of the Permian. We’ll be able to flex up or down depending on what we see in terms of the market.
Phil Gresh: (01:15:55)
Okay. So on the $19 billion, your base case would be, no, it would not decline. Is that the conclusion?
Certainly, at a $19 billion capital spending, it would not decline, no.
Phil Gresh: (01:16:07)
Speaker 6: (01:16:13)
Next, we will go to Jason Gammel with Jefferies.
Jason Gammel: (01:16:17)
Thanks very much. While we’re on the topic of the Permian, I was hoping that you might be able to address, Neil, what you’re seeing on the performance from wells that had been curtailed but are not being brought back online. Are you saying pretty flush production from those wells?
Yeah. Actually, it’s something we looked at very closely when we shut in these wells. We wanted to be sure that when we bring them back online that they come back at what I always describe as the same position on the type curve, and that’s indeed what we’ve seen. We were confident that if we shut in, we’d resume at or above where it left on that decline curve, and Jason, that’s what we’re seeing.
Jason Gammel: (01:17:01)
Excellent. Maybe if I could just shift over to the Downstream. You talked about the margin environment still being pretty poor. How are you able to, given the flexibility of your system, shift around product yields? I’m thinking really integration to petrochemicals and being able to more maximize feed into that system and away from fuels, and then also, how are you dealing with jet fuel, just given the significant inventories and lead demand for that product?
Yeah. I think, Jason, you have to start with jet fuel, frankly, because of all transportation fuels, jet is obviously lagging the most. From our perspective, it’s very clear that’s because of the lower international flights. That’s the biggest issue. When you produce jet, what are you going to do with it? You’ve got to push as much jet as you can into the distillate pool, into the diesel pool, and actually, the demand for diesel is quite strong, but the margins are still relatively low, and that’s because the refiners are pushing jet in up to the limits of the product quality, pushing jet in there, which is giving, if you like, an oversupply into that jet pool. It is interesting on the diesel or distillate demand. And just throw a little bit of data, we see U.S. truck vehicle miles back to the pre-COVID levels. That is a really significant point, and so once you see commercial transportation going back to those pre- COVID levels, that is important. But of course, we see passenger vehicles lagging and jet lagging a lot.
In terms of chemicals, chemicals is a really interesting story in terms of what’s happening in the demand for chemicals. It’s very different depending on the products that you’re making. If you are making products that’s going into the packaging or medical industry, so think things like polyethylene, the demand is very, very strong. And actually, polyethylene demand is up 2% year-to-date, but not all polyethylenes are the same. Some go into packaging and some go into durables and construction, so think of things like pipe, construction pipe in your houses. It’s very, very different. Overall, we see strong demand for products that are going into packaging, medical; weaker demand for products that go into auto and construction, and that’s important because it depends what feedstock you put into your steam crackers to make the right products. Of course, over the last quarter, we saw a contraction of the feed advantage between whether you’re cracking ethane, which of course is gas, or you’re cracking naphtha. There was little differentiation in the second quarter between those feedstocks. At that time, refiners were putting more and more liquids into their feedstocks.
Certainly, from a U.S. perspective, as this quarter has evolved in the last month or month and a half, what you’ve seen is the advantage for gas, i.e., ethane in the U.S. chemical plants, that advantage has started to open up again, which means more chemical producers are putting more gas in the feedstock of their chemical plants, which means they’re backing out naphtha. That’s really what’s happening.
Jason Gammel: (01:20:22)
Thank really helped me. Thank you for that.
Sure, Jason. Thanks.
Speaker 6: (01:20:30)
All right, and we have time for one more question. We’ll take that from Ryan Todd with Simmons Energy.
Ryan Todd: (01:20:38)
Great. Maybe just a couple of quick ones on the downstream. Could you provide some color around the time line for the Beaumont expansion and whether that will be impacted from the timing point of view in terms of what your eventual outlook is for Permian production over the coming years?
Yeah. I would tell you, Ryan, as I mentioned earlier on, we’re still working with our partners and our EPC contractors in terms of which of these Downstream projects that we are postponing, how long that postponement will be, and we’re just not in a position yet to communicate that externally Not because we haven’t fund our plans. We’re still working with our contractors on that, so in due course, we will give you some further details or more details on that. What I would tell you is there’s likely to be a postponement on that, the magnitude of that postponement on that project, and we’ll come back to you later on, whether it’s months or longer than that.
Speaker 7: (01:21:45)
Neil, if you don’t mind, I’d probably add to the fact that if you think about what we’re doing at Beaumont, it’s really all connected back to what’s going on in the Permian, so being able to sync those up is going to be pretty critical longer term.
Yeah, it is. It is. Sure.
Ryan Todd: (01:21:58)
Okay, thank you. And then maybe one final one. Over the last couple of quarters, we’ve seen pretty significant impairments from a number of your peers driven by both kind of short-term and long-term pricing assumptions as well as some certain assumptions on carbon transition. Can you talk a little bit about where you are in the process of revisiting some of those long-term assumptions, if anything, and in particular, where the oil sands have been hit pretty hard a number of your peers, where the oil sands falls in terms of your long-term views regarding this?
Yeah. No, I appreciate you asking that question. Thank you, Ryan. I always start with impairment saying it’s really quite difficult to compare between companies on write-offs and impairment. It depends on the quality of the resource. It depends on the carrying costs. It depends on your price margins assumptions. It depends on your development plans, and you also have to put this context on this. There are different accounting rules, as I think you’re aware. In Europe, IFRS goes straight to a discounted cash flow. GAAP rules are an undiscounted cash flow, so those are two very significant points, and I would just offer that as background.
For us, in addition to our normal monitoring for impairments throughout the year, we follow a very rigorous process each year following those GAAP accounting rules. It is part of our annual plan process. During that process, we refresh our views for long-term demand and supply and industry conditions each year. We look at that supply outlook. We look at the cost of supply for oil and gas. That drives the supply/demand outlook. That informs our view on prices, and as I’ve said previously and we have said previously, our prices are generally within the range of third-party assessments. We are going through that work now on pricing, and we have not finished that work. When we have finished that work, we will review it with our board, of course. But again, as we have seen previously, what we’re seeing so far, it is in line with third-party assessments. As part of that process and as part of that plan process, we look at the development plans for all of our resource base, and that would, of course, include oil sands. The key part here is when we plan to develop each resource, and when we’ve completed that work, if changes to our long-term views on prices or if changes to our development plans are sufficient, then we’ll follow the normal test for impairment. That’s the process we follow. We’re following that process this year, and that process will be finalized with a board review in November.
Ryan Todd: (01:24:47)
Does that answer your question?
Ryan Todd: (01:24:50)
Yeah. Thank you.
Speaker 7: (01:24:57)
Well, we want to thank you for your time and thoughtful questions this morning. We appreciate you allowing us the opportunity to highlight second quarter results and the decisive actions we are taking to manage through these challenging times and position ourselves for the eventual recovery. We appreciate your interest and hope you enjoy the rest of your day. Thank you, and please be safe.
Speaker 6: (01:25:21)
That does conclude today’s conference. We thank everyone again for their participation