ConocoPhillips (COP) Bank of America Merrill Lynch Global Energy Conference November 21, 2013 8:15 AM ET
Alan Hirshberg - Executive Vice President, Technology & Projects
I couldn't possibly introduce Conoco without acknowledging what a great job they've done at this new class of E&P. And we're delighted to, Al Hirshberg, he is here to join us. So without any further ado, Al, I hand over to you.
Thanks. We'll start with usual precautionary statement and you can study that in your book, I'm sure it has a fine print, but obviously we'll be making forward-looking statements today, so we need to have this up there.
Last May, when we spun off our downstream and our midstream assets to create Phillips 66, we really created a new offering in the marketplace. On the one hand, we were creating an independent E&P company and all the benefits of the sharper focus that come from the being a pure-play independent. But at the same time we maintain the size that gives us the size, the diversity of assets and most importantly I think the technical capability of a major. So that's really I think the way I think of the new offering that we've put out in the marketplace since last May.
So in terms of just a little bit of background regarding our size and our assets, we are the largest independent E&P company. You see over on the pie chart in the top right, we're currently producing around 1.5 million barrels a day, and the thing you note in pie chart is how liquids heavy we are. We got a very high percentage of liquids or LNG, which of course we're selling at liquids prices. And about a fourth of our production is the less profitable North American natural gas.
As I mentioned earlier, one of the benefits that comes from our size is we've got a very diverse asset base, significant scope and scale, geographic spread, we're in all the key plays that we want to be in around the world and use our significant technical prowess to prosecute those assets.
If you look though at our mix of proved reserves, where we're heavy in OECD, so where we're 80% of our proved reserves today of almost 9 million barrels of proved reserves are in OECD countries. Also at the bottom pie, if you look at our resource space, we've got about 43 billion barrels of resources at yearend 2012. And again, you see that about three-fourths of it is liquids LNG, about one-fourth is dry gas.
In terms of our strategy that we're using, as this new offering in the marketplace, really as I said, we see our diversification, our scale, our technical capability as a competitive advantage. And in terms of our investment strategy, we've moved from the way we really built ConocoPhillips in the 10 years, leading up to sort of the 2009, 2010 timeframe, which was growth through M&A to a peer focus on organic growth, where we're really not interested in the M&A game in our current strategy.
So we have a very significant portfolio of high-margin, high-return investment opportunities already in our organic portfolio. So we're really don't have any focus on M&A work at this point in time. So we're building, the way we've built that that advantage portfolio is really through this technical capability that I was talking about earlier.
We've built a first class capability both in oil sands technology, enhanced oil recovery, unconventional reservoirs, deepwater. For example, the deepwater technical capability that we built in high performance computing, high-end subsurface imaging is what's allowed to us acquire over deepwater acreage that you see in our portfolio, now that's already starting to pay dividends in the Gulf of Mexico, as I'll talk about a little bit later.
We've also been since 2009, pretty aggressively divesting non-strategic assets, which has also helped us improve our returns and also provided cash that helped us balance our cash flow from operations versus CapEx and dividends in this time period that we're in, where we don't have those balance yet from our regular operations.
We're just about finished up with really that divesting and non-strategic assets for the most part and in the future we'll continue to prune and rebalance. So going forward, we think we have a lot of good high-return options and choices built into our portfolio.
So with all that, what do we expect to be able to deliver? Of course, at the top of our list this was particularly important for a company of our size and scope, a relentless focus on safety and day-to-day execution. Next on our list, compelling dividend. You'll hear me talk about the dividend quite a bit today. We put the dividend up very high in our list of priorities and plan to continue to pay an attractive dividend and to continue to grow that dividend over time.
We're also offering a 3% to 5% compounded annual growth rate on production, while at the same time growing our cash margins per barrel 3% to 5% compounded every year. So that's really our value equation. You add those two together 6% to 10% growth per annum in our cash flow, as a company. And I'll show you a little more detail on how we're going to do that. And of course, as a part of that, we also have an ongoing priority to improve our returns, our returns on cap employed.
Have I mentioned the dividend yet. The dividends are high priorities to cash flow, not everybody likes that, but we do. We think it enhances our capital discipline, it's a predictable part of our shareholder returns. You could see on the right and it's a bit differential relative to our peers.
Shown in blue is the independent, so we're paying almost a 4% dividend yields right now. So that's well above our independent peer group and also above our U.S. IOC peer group, and below the European majors, it's basically the bars that are above us. We did increase our dividend 4.5% last quarter and we expect to be able to continue to increase our dividend.
In terms of capital allocations, just a quick summary here, that shows you where the money is going on the capital side. We said when we rolled out the company last year that as part of this 3% to 5% growth plan in production, we thought we were going to spend about $16 billion of capital a year.
Won't be the same every year, it could be plus or minus $1 billion, but on average we expect that to achieve that level of growth. That's about what we'll be spending $16 billion. And you could see how it's broken out there, the bottom 10% protecting the base with maintenance type expenditures.
The next lag and these are color coded to match the production plot that you see on the right. The next lag of about 45% on development programs. So that's where all our unconventional development is as well as other in-field drilling and that sort of work around our legacy assets is all in that blue wedge. And you could see on the production plot on the right, between that base maintenance money and the development programs, we're just about able to keep our production flat at about that 1.5 million barrels a day across time.
Then that top green wedge that really drives our growth, it comes from our major projects. So we are spending about 30% of our capital on major projects, and now I'll show you some examples of where that money is going in a few minutes. And we add that on top, that what's driving that 3% to 5% annual growth rate.
We're also spending about 15% of our capital on exploration and appraisal to try and really none of that is expected to deliver any significant volumes in this time period up to 2017, but that money is really designed to keep doing a good investment opportunity beyond 2017.
So to give you some feel for how we're able to grow production and gross margins at the same time, we put together this little plot to kind of show what the margins are in the areas, where we have the growth. So we have five significant areas driving our growth between 2012 and 2015 over that five years time period that is shown there on the map.
And on the plot down on the bottom right, we've just taken a standard price deck, which is actually not too different than where today's prices are, $100 Brent, $90 WTI, $70 WCS and $3.50 Henry Hub. We just take a flat price deck like that, that's what we've used to calculate those margins that are shown in the plot at the bottom right. So the red dot shows you under those kind of pricing conditions, where ConocoPhillips in 2012 was at. So our after-tax cash margin per barrel is about $25 a barrel.
Then each of those dots corresponds to the five areas of growth that we're going to have over the next five years, the net growth in those areas. And you can see on the vertical scale, how much net growth we expect from each of those areas. And then on the horizontal scale, you see under those same pricing conditions, the after-tax margins per barrel that we expect to earn.
So you can see that every one of our growth areas has a substantially higher cash margin under the same pricing conditions versus where the company was say in 2012, which is the red dot. So that's gives you a little insight into how at the same time we're growing our production wells, we're going to grow our margins.
This is driven, because of these growth areas are very heavily weighted toward liquids and they are in locations that tend to have lower tax rate than our corporate average tax rate. So both of those effects are what are helping drive those higher after-tax margins.
So we're about 1.5 million barrels today. In 2017, at the end of this five year period, I've been showing, we're going to be at 1.9 million barrels per day. So that's what the 3% to 5% compound annual growth does for you.
It's a gain of about 400,000 barrels per day net. So after you take out the decline from our existing assets, our existing production, our new production will offset that decline and grow 400,000 barrels a day between now and 2017. So this plot, the blue area plot, just shows you that growth from zero to 400,000 barrels a day, so that's net growth.
And then on the right just shows you the kind of products that make up that net 400,000 barrels of growth. And you could see that 75% of it is oil and then the next 15% wedge is LNG, which is being sold at oil pricing, and then a small wedge of NGL and international gas. Notably, absent from the plot is any North American natural gas, because we won't be growing, we're not really investing any significant money in North American natural gas over this time period in our current plan.
I want to mention also returns, return on cap employed. Here we're just comparing ourselves to our independent peers, it's not too useful to compare to the IOCs on ROCE, because they've got the downstream and chemicals, and as that moves around, it doesn't make for a very good comparison with a pure play E&P, so we're just plotting here against the E&Ps.
We're pretty well-positioned on our return versus our competitors, but we're certainly not satisfied with this. And as we develop that growth from those five areas that I was just showing you, we'll be growing our returns at the same time, due to the capital efficiency of the kind of projects that we're taking on.
So next, I want to get into a few details around where some of the specific projects and the work that we're doing is going to bring on these increased margins and production. We like to think of this in the same four pieces that I showed you on the CapEx bar a minute ago, the base, the development projects -- the development side, the major projects and then the exploration and appraisal. So I'll kind of take you through in that order.
So first is the base. We do have a very high-quality legacy setup of base assets, and so we put a lot of effort into protecting that base making sure we've got good asset and operating integrity, that we're doing all the right things on maintenance and reliability, proper surveillance, optimization of that production. And so doing that we're spending a little bit of money on it, it allows us to continue to have a high-quality base production to build our growth on.
If we look at the development programs next, so this is the unconventional developments and other places where we're drilling around existing assets to enhance production and that's what we call development program. You could see there, the main areas around the world, where this is coming from and each box gives you the amount of growth. So overall in the five-year period from development programs, we expect to add about 600 million barrels a day of production.
You could see on the plot in the bottom right where that comes from. So the bottom wedge the first 250,000 barrels a day of that 600 of growth is from conventional reservoirs. The rest of it is all from unconventional reservoirs in North America. So this gives you an idea of how much Eagle Ford, Permian, Bakken we have built into this 3% to 5% growth. And also you do see a small wedge at the top on the order of a 100,000 barrels a day of growth over five years, from all our other unconventional North America put together.
So this was, when we first rolled out this plan to the marketplace last year and as we talked about it on our Analyst Day in February, these are the numbers
that we were using to build that plan that we showed at our Analyst Day. I'm going to show you a few examples today where we're actually in 2013 outperforming what we have laid out here.
I mean obviously that top wedge we have a lot of other unconventional assets that we're working on in North America and as those de-risk and become more mature, we have the potential to add more volume than what we have there, but I am just showing you here what we have built into this case that we've built that leads to the 3% to 5% annual growth.
So first piece of this I want to talk about is the Permian conventional. So this is not the unconventional that we have in the Permian, but just our conventional assets that's centered on the Central Platform Basin and the Permian Basin. We expect to spend about $3 billion investing in this area and have an F&D cost around $15 a barrel. We've got 1 million acres available to us in the heart of this area to develop, so a lot of different work. It gives us a about a 7% compound annual growth of production across this period.
One of the interesting things though is the little bar chart at the bottom right. It gives you a little more insight into how we're improving margins as we build this production. On the bar on the left shows you the mixed oil, NGL and gas in our current Lower 48 production in 2012.
And then the bar on the right shows you all the new production that's coming on from our new investment what the mix is, so you could see that the much higher oil mix and a much smaller gas mix, essentially all of that gas is associated gas is just coming with the oil. So that change in investment strategy versus what we've been in the past is part of what drives the improved cash margins in the U.S.
The Bakken is another good example here. We have in our plans to spend about $4 billion over this time period. We've got a lot of drilling locations left to go. We've got over 600,000 net acres, results in a pretty good growth rate. Interestingly here, if you look at the plot, again that's the number that's built into the growth for 1.5 million to 1.9 million barrels a day, the case that we're showing you.
But actually if you've been listening closely to our quarterly earnings calls and look at that plot, this is one of an example you could see we're clearly outperforming what we had kind of built into our case, because we're going to exit this year in the Bakken north of 40,000 barrels a day. If you kind of add all of that plot, you can see that the Bakken is performing better for us this year than what we had projected back at Analyst Day back in February.
And in fact, I could say the same thing about the Eagle Ford. The Eagle Ford is really our highest quality unconventional play that we're in. We've got over 200,000 net acres, and have many, many drilling locations left to go. We've got decades of development work left to do in the Eagle Ford.
At the time that we put together our growth case to 1.9 million barrels a day, we had the production plot that's shown here that showed us growing to a certain level and then kind of plateauing at, I guess, if I look at the plot, it's on the order of about 130,000 barrels a day.
If you look at where our production is right now in the Eagle Ford, we're north of 130,000 barrels a day now. So that gives you another idea of how the Eagle Ford is performing for us versus what we had kind of built into our plans earlier this year, when we were putting together our Analyst Day deck. And again, in the bottom right, you see the same kind of improvement in mix between liquids and gas.
If I move on next to major projects, having hit most of the key development areas, the major projects are going to add about 400,000 barrels per day of new production over the same five year period, and you could see where it's coming from in the various geographies around the world. All of these volumes are coming from projects that are well underway. This is not things we're hoping to discover or that we haven't made a commitment to develop yet. These are all projects that are well underway and in hand.
And so you could see that it's spread, significant wedge is out that is in Canada in the oil sands, plus in U.K., Norway, Malaysia, Australia and smattering of other places that give us that 400,000 barrels a day. Generally, I would say that all of these projects are in relatively low-risk countries, low-risk geographies and also low-risk geology. So this is a very confident set of growth projects for us, and I'll take you through some key examples here.
First is the oil sand. I think most of you know, we have a very high quality asset base of oil sands between Surmont, Foster Creek, Christina Lake. Those are all assets that are top cortile geology in the oil sands and so we're in an advantage to position with our large oil sands asset base.
And we have a continuing stream of phases of project coming on production over this five year period after 2017 that results in that 16% annual growth over the period, getting us up to around 200,000 barrels a day of net oil sands production, out in the 2017 timeframe. And again, just a little reminder in the bottom right, the high margins that we expect to get from this.
Next, the U.K., it's time we want to talk about, we just announced yesterday the startup of our Jasmine project. The Jasmine project is by far the biggest volume wedge that makes up that volumes, that you see there in green that grow to about 55,000 barrels per day by 2017. So Jasmine just started up this week, I think it says, on the chart on track for late 4Q startup, so that's kind of old news. Now we've delivered that one and started, it's ramping up now.
The good news on Jasmine, we pre-drilled four wells, this is high-pressure, high-temperature reservoir. So it's difficult technically to develop, but these are very prolific wells. When we pre-drilled these wells, they came in on the high-side in terms of the geology versus our pre-drilled expectations. And these wells are capable of very high levels of production. These will be the most prolific wells in the corporation actually as they come on.
And so this is a platform that on a gross basis can handle about 140,000 oil equivalent barrels per day. And we've got more than that in well capacity with these four wells. So we should ramp this production up pretty quickly at Jasmine. I think that's a key milestone for us in starting to grow our production from this point going forward.
In Norway, we've also got a series of projects that build to around 60,000 barrels a day of incremental production over this time period. Ekofisk South, the first one that's mention there, we've already started up. We started it up last month. Eldfisk II, we'll startup next year. So these are just additional platforms that we're putting in, in a Greater Ekofisk area that continue to allow us to bring on new barrels, new production there.
Malaysia is an interesting story for us. If you go back just a handful of years, we weren't even in Malaysia. It's a new presents for us. We were at zero production last year. We're starting to grow production with our Gumusut early production system and then the full field Gumusut is expected to come on early next year and that will give us our first wedge of real production growth in 2014 in Malaysia.
But we expect to grow this up to 60,000 to 70,000 barrels a day and we're continuing to have good luck there in terms of acquiring additional acreage. We've now got our first operated blocks there and we'll be doing our planning now for drilling some of those that are in the deepwater. And so you could see where Malaysia is on the plot at the bottom right in terms of the attractive margins that we get from there. And we'll be continuing to make some significant investments in Malaysia in brining on those volumes.
APLNG is one of our monster projects that will reach its peak spend next year. It's something we've been spending money on for a number of years now. Everybody is always asking us how is it going on Curtis Island. There is three different companies trying to build projects at the same time. And I can tell you that, I'm really very pleased with our project execution at APLNG.
The work on the LNG plant on Curtis Island, what we call the downstream part of the project has stayed on, are ahead of schedule from the beginning. It's just run smoothly and it has stayed on budget. So we despite all the difficulties with the Australian labor and materials and trying to work on Curtis Island with everybody around us, all of that work has stayed on or ahead of schedule and on budget.
The upstream part of the project, the part out in the well field, where we're building the pipelines and drilling the wells has hit some cost issues driven by regulatory issues and some logistics issues. And so as we said earlier this year, we expect that that will increase the cost of the project on Aussie dollar basis by about 7%, all driven by things happened the well field, not to part everybody was so worried about on Curtis Island.
So you see the net growth in production there in the green wedge up to about 70,000, 80,000 barrels per day. So the first train at APLNG, its two trains by 4.5 MTPA each. First train should startup in 2015, the second train in 2016. That's what gives you that growth wedge.
So next, shift to that fourth area that I mentioned earlier, our exploration and appraisal. This little world map shows you the key places where we're spending money around the world. In the red is the unconventional locations, and in orange the conventional reservoirs that we're exploring. In the red, you see the usual suspects there in terms of North America, in the places where we have significant acreage positions.
We're investing money to Duvernay, the Muskwa, Montney and Canol in Canada. The Wolfcamp, Niobrara, Avalon in the U.S. are all places where we're expecting to spend significant dollars over this timeframe. And then you see four red spots on the map outside North America. Colombia, Poland, the Sichuan Basin in China and the Canning Basin in Australia, those were the four areas outside North America where we're currently doing exploration for the unconventional side.
Then you can also see populated on the map, in addition to a number of places where we've been for a long time like Indonesia, Australia. A lot of relatively new deepwater locations where we're spending money, the Gulf of Mexico, of course, where we really built a very sizeable acreage position over the last three or four years.
You see Greenland, Angola, Senegal, we've got the deepwater Malaysia, I mentioned earlier, Bangladesh, some of the acreage in Australia. So we've built a worldwide deepwater portfolio. We've already had some significant success in the Gulf of Mexico. Next year will be the big year for Angola. We have a new-build drillship coming early next year that will allow us to start our operated exploration program in Angola next year.
So I'll take you through few of these examples where we're spending exploration and appraisals dollars. First is in the Permian unconventional. I know this is an area of a lot of excitement out in the marketplace today for us. It's still relatively early days in terms of our view of how this is going to perform for us. And we don't have huge volumes built into our production wedge up to 2017 today, but we do see a considerable potential.
In the Delaware Basin, we've got about 150,000 net acres. So we're chasing the Wolfcamp, the Avalon and the Bone Spring, all the usual suspects that you hear us talk about. And in the Midland Basin also we've got about 90,000 net acres and chasing the Wolfcamp. We've continued to be able to acquire additional acreage in these areas even recently at attractive kind of organic growth kind of pricing.
So we have early wells that we've drilled here that have been very successful in these areas, where we're continuing to do pilot work and really trying to make sure we understand these reservoirs before we move into a more extensive kind of investment mode. So that's why we have this chart in our exploration and appraisal part of our deck. We're not ready to declare how the pace that we're going to go develop this acreage out. We're still making sure we understand it before we get into manufacturing mode in the Permian Basin.
In terms of the deepwater, I mentioned Angola earlier we're the operator for blocks 36 and 37. And we've processed our 3D seismic and have some very significant prospects that we've identified that we've got plans to drill. We've got a two-well commitment on each of the block, so we're going to drill a minimum of four wells here. And so we have this deepwater drillship that's at Samsung right now that will be coming out in the first quarter of next year. And by the second quarter, we should be out there drilling on our first prospect.
So given what's happened on the acreage right around us since we acquire these blocks with the discoveries that have been made by others, it's left us pretty optimistic and really eager to get started drilling these two bocks. Between the two of them, one is over 2.5 million acres, so these are not like Gulf of Mexico block, these are very large blocks that can give you a lot of running room if you're in the right zip code.
Also just wanted to mention Senegal, some of you may not have noticed this one, there was a little announcement that came out not too long ago, but we have formed in some blocks back in July in Senegal. And so that's 650,000 net acres and these are going to be drilled fairly soon. We expect that we'll be able to drill two wells here next year.
This is non-operated for us right now in the exploration phase and then we have the option to take over as operator in the development phase, if we make a discovery here. So Senegal is another African deepwater play for us that we're optimistic about. You can see the blocks there on the map.
And finally, the deepwater Gulf of Mexico. As you know, we've already had three significant discoveries. We've built up as you see on the yellow bar, it's a very significant acreage position and we've already had discoveries at Shenandoah, Coronado and Tiber. We're currently drilling at Gila and at Deep Nansen. We're going to have results from those fairly soon.
And so I think you're going to continue to see, we're very happy with the kind of results we've been getting and the quality of the acreage we've been able to acquire using our technical capability on deepwater subsurface imaging. And I think you're going to continue to see a stream of good news from us on our Gulf of Mexico deepwater results.
So just to wrap up, I think from an operating standpoint, we're at a significant inflection point. Just for me having in the same week, the closing of our Kashagan sale, which to me kind of symbolizes the end of shrink to grow. We got our $5.5 billion in the bank and got out of Kashagan. That was the biggest thing we were trying to sell, that we've been trying to sell for about three years now. It feels good to be out of it.
And in that same week, we started up Jasmine, which is these very prolific hot HPHT wells in North Sea that is to me kind of symbolizes the growth that we've got started coming forward. We're really at that inflection point, where we're done with shrink to grow and it's going to all be growth, this 3% to 5% annual growth going forward. You can see visible results already from our exploration programs in the Gulf of Mexico, and I think we've been running well, continuing to run well as a safe operator.
On the financial side, we've maintain a strong balance sheet, if you look at were our cash balances will be at the end of the year, particularly with the Kashagan money. Even though we have been spending more, if you add our CapEx and our dividends, we've been spending more than our cash flow from operations. We still maintain a very strong balance sheet with the cash that's come in from asset sales.
You can already see in our numbers that margin improvement that we're getting this year versus last year and the focus that we've got on improving returns, so we feel we are delivering on the value proposition. We do have two announced sales that we still need to close, Algeria and Nigeria. So both of those are about $1.75 billion each, and so we're still eager to close each of those and you'll see news on those as we go forward. And then if I forgot to mention it until now, the dividend is our top priority.
Al, thank you very much indeed. Folks we've got some microphones, if anyone has any question, please make yourself known, we've got about 10 minutes for Q&A.
Earnings Call Part 2: