Patrick de la Chevardière - Chief Financial Officer.

Iain Reid - Macquarie Theepan Jothilingam - Exane BNP Paribas Brendan Warn - BMO Capital Markets Thomas Adolff - Credit Suisse Oswald Clint - Bernstein Rob West - Redburn Biraj Borkhataria - RBC Lydia Rainforth - Barclays Irene Himona - Societe Generale Martijn Rats - Morgan Stanley Henry Tarr - Goldman Sachs Anish Kapadia - Tudor, Pickering, Holt Christopher Kuplent - Bank of America/Merrill Lynch Jon Rigby - UBS Kim Fustier - HSBC.

Hello. Patrick de la Chevardière here. Most of you know that we had our Investor Day in London last month. Our messages are straightforward. We are committed to being excellent at everything we can control and to getting the most out of our existing assets.

We are delivering upstream production growth of more than 4% this year and continuing to cut costs, and this positions Total for superior cash flow growth. We expect the environment to remain volatile, but based on our 2015 and first half 2016 performance, Total has been the best performing major whether the oil price is rising or falling.

And we are using active portfolio management, combined with disciplined organic investment, to build the portfolio that will take us into the next decade. Since the Investor Day, there have been a few highlights. The sale of Atotech was signed for $3.2 billion, about 12x EBITDA in cash. We anticipate closing the Barnett preemption in the coming days.

We just announced the strategic alliance with Petrobras that should open up some new some opportunities in Brazil for upstream and downstream gathering power. Kashagan started up this month and it should add 35,000 barrels per day of oil net to Total on average next year. And for the most recent dividend, the take-up for the scrip share was 64%.

The third quarter 2016 environment remained challenging. Brent was $46 per barrel, stable compared to the second quarter, but our average realized hydrocarbon price fell by 2%. And European refining margins were $25 per ton, a decrease of $10 per ton compared to the second quarter, but they are back above $40 per ton since the beginning of October.

For the results, we reported a solid set of third quarter numbers, broadly in line with the second quarter. Adjusted net income was $2.1 billion or $0.84 per share, a decrease of 5% compared to the previous quarter.

However, operating cash flow before working capital changes increased by 13% to $4.5 billion, more than covering organic CapEx of $4.1 billion. We will achieve OpEx reduction in 2016 of more than $2.7 billion compared to a target of $2.4 billion and our CapEx outlook for 2016 is $18 billion or the bottom of our range for the year.

Year-to-date, our pre-dividend cash flow breakeven is around $45 Brent, in line with our guidance, but this does not include the $3.2 billion from the sale of Atotech. As usual, we will cover the numbers by segment starting with upstream. We are continuing to deliver upstream growth well ahead of our peers.

Hydrocarbon production increased by 1% quarter-over-quarter and by 4.3% year-to-date. We have started up all 5 major projects planned for this year, including Kashagan in October, on top of 9 startups in 2015. We are on track for new projects to add 350,000 barrels per day in 2017.

And at $60 Brent, this represents close to $3 billion of incremental cash flow. Cash flow is our primary metric, and the important number for the Upstream is the operating cash flow before working capital changes, which increased by $470 million or 21% to $2.8 billion in the third quarter compared to the second quarter.

Production from the new project is accretive to cash flow on a per barrel basis, so we are benefiting from the ongoing shift in the production mix as we add new barrels. In addition, we reduced OpEx by about $200 million in the third quarter compared to the second quarter. And year-to-date, we are below our target for the year of $6 per Boe.

So you can see that Upstream is performing well, particularly in terms of increasing operating cash flow and reducing the breakeven. Adjusted net operating income for the Upstream was $877 million, a decrease of 22% compared to the second quarter. The tax rate was 28% in the third quarter compared to 3% in the second quarter.

The contribution of equity affiliates in the second quarter was higher than average due particularly to strong results from Novatek in Russia. Just a few words about our LNG businesses, LNG volumes have grown by 5% year-over-year for the 9 months and represent more than 30% of the upstream net results.

And this is part of the reason why we have outperformed our peers. Moving to the downstream, adjusted net operating income for the downstream was $1.5 billion in the third quarter, a 5% increase compared to the previous quarter. The strong contribution from downstream has been the backbone of Total resilience.

European refining margins were lower, but throughput volumes were higher. We are on track to reduce the breakeven to less than $20 per ton and this will further strengthen our ability to resist volatility in the environment. Marketing is performing well, generating a return on capital employed of about 19%.

New Energies contributed $100 million in the third quarter, reflecting the completion and sale of the Henrietta solar farm by SunPower.

In terms of cash flows, the downstream generated $1.65 billion in the third quarter, equal to its contribution in the second quarter and represents $5 billion of cash flow generated year-to-date, so on track to deliver $7 billion for the year as announced in February when we also indicated that $7 billion is a sustainable level of cash flow.

Finally, the corporate section, our credit internal organic breakeven is close to our guidance of $45 per barrel Brent for the 9 months. Organic CapEx were $12.8 billion. Operating cash flow before working capital changes was $12.2 billion with Brent at $42 per barrel on average year-to-date.

There was no net impact from net asset sales, and the sale of Atotech is not included. The group effective tax rate was 22% in the third quarter, flat compared to the previous quarter. The increase in upstream tax rate was offset by a decrease in the downstream tax rate due to the weight of New Energies in the results.

Gearing was 30.6% at the end of the third quarter, stable since the start of the year despite the challenging environment. To summarize, we are executing and delivering according to plan. Third quarter results were clean and solid. We are continuing to benefit from the integrated model.

Production is growing by more than 4%, and we are continuing to cut costs. So, I am ready to begin the Q&A. And as usual, I am asking you to limit yourself to 1, 2, 3, 4 questions at a time. [Operator Instructions].

Thank you. [Operator Instructions] We will take our first question now from Iain Reid from Macquarie. Please go ahead..

Hi. Thanks Patrick.

Can I just ask a question about SunPower, the $100 million you talked about in new energies for the quarter, I presume most of that was SunPower and can you give us some guidance about how lumpy that kind of level of contribution is going to be going forward, I understand it’s because they sold an asset during the quarter, is this something we should expect to see every quarter or should we look at it terms of frequency.

And second question is on chemicals, can you give us an indication of what you are seeing in terms of margins and how you see those go into the fourth quarter and into next year?.

Okay. Thank you, Iain. I have some difficulties to answer on SunPower because it is a listed company and they will broadcast their results on the market and some forecasts, I assume at the beginning of November. As it is a listed company, I don’t want to provide any insight to anyone listening to this conference.

Nevertheless we, within the new energies, posted $100 million contribution in net operating income this quarter. This is due to the completion and the delivery of the Henrietta solar farm in the U.S. by SunPower. Henrietta is a solar farm of about 100 million megawatts. I am sorry, but I can’t say more than that.

On the petrochem, yes the petrochem have remained strong because the polymer demand is strong and feedstock are cheaper. This is another illustration of the added value of being present for the full line chain. We are taking full advantage of the margin, notably thanks to the large integrated platform we have in Asia and in the Middle East.

Just to give you an idea, the order of magnitude given for the third part of the year remains valid, but can represent a bit more than a third of our refining and chemical result for the first nine months. I think this gives you an idea of how strong were the margins and we don’t see any margins going back at the moment..

Okay. Thanks..

Thank you. We will take our next question now from Theepan Jothilingam from Exane BNP Paribas. Please go ahead..

Yes. Hi, good afternoon Patrick. Two questions, please. Firstly, could you just maybe give a little bit of color on what’s changed to bring the CapEx towards the lower end of the range, whether – what moving parts are, whether it’s project phasing, deep stream refreshes or FX.

And then my second question is just in the context of the strong progress you are making on CapEx costs and also disposals, can you just talk about how you think about the process on removing the scrip? Thank you..

Okay. Theepan, I am glad to see you back on to the market. First question about CapEx, I remind you that despite the few weeks you were not attending the market, that the financial discipline is the core of our response. The core of our response to the new environment. And we continue and invest through the cycle to taking advantage of the deflation.

We are well in line with our target. We gave the target $18 billion, $19 billion before. We are at the lower end of this target, this is true. We have spent a little bit less than $13 billion CapEx in the first nine months of this year and we should invest $18 billion in 2016.

You – I shall recall you also that, currently the deflation we are enjoying on CapEx is at about 30%. So there are two effects on the CapEx new figure. The first one is obviously we are able to harvest the deflation. And second, we have a better visibility on year end at the moment.

And the second is I think we are more efficient in handling our operation. A few examples, on Egina, the drilling campaign is honestly going very well, with the average expected number of drilling days per well reduced by 20%. This is part of all those CapEx going down. So the tricky question about the scrip dividend, which is not difficult to answer.

We make clear that at $60 a barrel in 2017, we will remove the discounted scrip dividend. And we are committed to remove this dividend – it’s not the dividend, sorry, the scrip dividend, at $60 per barrel.

The decision itself from the discounted scrip dividend for 2017 will be validated during first half 2016 – ’17 and will be sanctioned by the Annual Shareholder Meeting, which is in May. So let’s assume that for let’s say, three months, we enjoy an oil price above $60 first quarter next year.

My view is that the Board will ask the shareholder meeting to remove the scrip dividend. Actually, it doesn’t need to ask to remove it. It just needs not to ask for another scrip dividend.

Of course, if we are in a very volatile environment at the beginning of next year, let’s say, between $50 and $55, the decision to maintain the scrip dividend will be going for the shareholder meeting.

And then if the oil price bumps up later on, we can remove the discounted part of the scrip dividend in order to reduce the take in share of the dividend..

Okay, thank you..

Thank you. We will now move to our next question from Brendan Warn from BMO Capital Markets..

Yes. Thanks Patrick and good afternoon and thanks for the opportunity to ask question. Just two questions, if I may. Just in terms of Nigeria and the wildfire impacts in Canada, what do you expect in terms of impact in fourth quarter in terms of the security situation in Nigeria.

And then just secondly, in terms of just – I know we have just had the Capital Markets update, but just so I am clear on the project delivery in 2017 and particularly Ichthys, how that’s going in terms of delivery in 2017 rather than slipping into 2018, please?.

Okay. Brendan, thank you for your question. First question about the impact of the fire in Canada, which is currently over, it was – the impact on the third quarter was negligible, I think it was 4,000 barrel per day in aggregate at the end of the quarter.

On Nigeria, the security condition impacting production mainly related to periodical shutdown on the onshore pipeline due to illegal connection and bunkering. The impact for this quarter was about 30,000 barrels per day. I have to say that the offshore facilities are not impacted.

Very frankly speaking, I don’t have any perspective to see and to know what’s going to happen next quarter. It seems that the situation is improving, but that’s it. It’s just a feeling and I would not beat on that. The question on the project delivery, mainly your question about Ichthys where we own 30%, the overall progress is about 90% at the moment.

According to the operator, the startup is scheduled in second half 2017. Construction of the CPF and the FPSO in Korea is complete and commissioning works are ongoing, ready for sail-away by end of 2016 and then sail-away to the field at appropriate timing. Exact timing is yet to be confirmed by the operator.

But according to this operator, works are ongoing to keep startup date unchanged. All modules for the LNG plant have been delivered to Darwin and commissioning is in progress. And the pipeline, I remind you, was completed in 2015. That was for Ichthys. Thank you..

Thanks, Patrick..

Thank you. We have a question now from Thomas Adolff from Credit Suisse. Please go ahead..

Hi, Patrick. Two questions for me as well.

Shall I blame you or someone else in the finance department for Total’s working capital management so far this year? What has gone wrong and when should we expect the full reversal of the working capital you built in the second quarter? Second question on LNG, you are developing a number of LNG projects, Yamal, Ichthys, GLNG is ramping up.

And obviously, you have some Greenfield optionalities, Elk-Antelope or Papua LNG you call it now. But in your view, for a company like yourself or for anyone, what is the critical mass needed really to hit the sweet spot of value and risk in LNG and do you think you have a gap there right now? Thank you..

So, the working capital, I know it is not a big figure, but working capital improved by around $200 million this quarter, basically, all branches getting better but one, which is the E&P division. And no, we are going to tackle this issue in the E&P division.

The point is that when you recognize that you have an issue in the working capital, it is not a matter of weeks to reverse it, it takes months. And I have no doubt that we will continue and improve this working capital figure in the fourth quarter. We are working on it. I recognize that the effect of this work at the third quarter is not tremendous.

We are not disappointed that – because we know that it will take some time. And all teams are working to reduce this impact at the moment. And obviously, we expect more results by year end. On LNG, Thomas, I would like to remind you that LNG representing 15%, 15, of our production is making 30% of the upstream net income.

So, it is a good business, whatever you can earn elsewhere. I remind you that when we sign and launched an LNG project, we have contracted all the volumes produced or 95% of the volume produced by this project. This is the case for Ichthys, for GLNG, for Yamal when it will start, all the volumes are contracted.

And I think we already have the critical mass. We are number two in the world. That’s not so bad. What matters is that the portfolio size in trading and downstream. And I think we have both. So, we are profitable now and I would say very profitable, because our scenario is different than other companies. We contracted long-term. We don’t play spot market.

And we are profitable now and we will remain at the same level, being profitable..

Okay, thank you..

Thank you. We will now take our next question from Oswald Clint from Bernstein. Please go ahead..

Yes, thank you for the question. I wanted to ask about LNG as well please. Your comments on the good volume growth you have had this quarter and across 2016. I guess some of the big Asian importing countries have been a bit soft in terms of their imports.

So, my question is are you still – is Total still placing your volumes into those legacy countries or are you having to place them elsewhere despite some long-term contracts? That’s the first question.

And then yes, you mentioned the critical mass in LNG, I note the other comments on – in marketing and services today about some parts of the business lacking critical mass. Is there a big portion of the marketing and services business that’s lacking the critical mass and could be for sale at some point? Thank you..

So, back to the LNG, yes, we had good volumes and good results. And usually, we were selling long-term volumes to Japan, Korea, Taiwan and lot of our marketing activities to Mainland China, then to Indonesia. And then I think this is part of our business to provide LNG to new countries willing to buy LNG.

And I think we are flexible enough and we have a large portfolio, which enables us to sell long-term or medium-term volume towards so-called new countries in the market, like for instance Indonesia. And I will remind you we started to sell to Mainland China also obviously, which is a great importer at the moment.

On marketing and service, is marketing and service lacking critical mass somewhere? I would say that there is one country, where in Europe we are ready to sell, which is Italy in our operations with ERG. So, we have launched a process, Total and ERG together, to sell our affiliate in Italy.

I remind you also that we had the same feeling because of the difficulty of the country itself, that was not a question of critical mass, but that was a question of difficulty we face in our marketing and selling business. We sold our affiliate in Turkey.

At the contrary, we increased our operation in Africa by what we call the Gasco operation when we buy assets in Africa, in Kenya, Uganda and Tanzania. So, we are rotating the portfolio where we believe we have plus to add and where we could make some money.

And exiting the countries where basically we think we are no more able to improve our business..

Understood. Thank you..

Thank you. Our next question today comes from Rob West from Redburn. Please go ahead..

Hi, there. Thanks for taking my questions. I would like to ask two, please. One from Nigeria and there is comments in the press about NNPC leaning more on partners and JVs for cash flow.

And I was wondering with the working capital question that Thomas was alluding to, are there any JVs around the world where you have more cash sitting in there helping your partners at this time, which we should think of as coming back in future quarters? That’s question one.

And question two, I would just be interested to understand a bit more of the difference between the P&L tax and the cash tax this quarter, and – that one is a bit harder to back out from your disclosures. So, any numbers you could give around the specific cash tax paid would be super useful? Thanks very much, Patrick..

So Rob, don’t worry, we will always take your question in the future.

Your question about Nigeria potentially having not paid its share of some costs and does it happen elsewhere, I have to say that our unpaid exposure in Nigeria is mostly covered by what we call [indiscernible] agreements, which are in place where we recover our debt through taxes and oil off-take. Of course, this creates some working capital impact.

But that’s not explaining the whole working capital effect we have at the group level at the moment. This is a small part of it. The question about the P&L and the deferred tax and so on, the effective tax rate for the group was about 22% this quarter, stable in comparison to last quarter.

The extreme tax rate is back in third quarter to a more standard level. I mean by that, that the 3% tax credit rate we had last quarter was not normal. It was impacted by a deferral tax asset booked in some countries, which has a positive effect on the income, but no cash effect.

In the downstream, the tax credit has been lower this quarter, mainly thanks to weight of new energies, which is benefiting from a lower tax rate. I don’t have the exact answer for you how much exactly we pay in cash and how much is deferral. But Mike Sangster will call you back on that matter.

But I would say that in some countries, we are close to the tax breakeven. So some months, we are paying taxes. Some months, we are not paying taxes and making some tax losses. So it’s quite difficult to answer, but we will answer you..

That’s really clear. Thanks very much..

Thank you. We have our question now from Biraj Borkhataria from RBC. Please go ahead..

Hi Patrick, I have a few quick questions.

First one was on Brazil, I was wondering to get your thoughts on your strategic alliance with Petrobras and how you expect that to play out over the coming years, in terms of what you are looking for in terms of new JVs or assets, are you looking for early stage appraisal activity or exploration or would you be interested in volume also.

And then the second question would be on the Barnett shale acquisition, which looks like a good opportunistic deal, can you talk about what level of CapEx is required to keep production flat at that asset?.

First question on Brazil, honestly we, at Total are very happy to enter into such an agreement with Petrobras. We do recognize Petrobras as being a good operator. They have great assets and we like to work with them. We have just signed this MOU for this strategic alliance. Obviously, it opens new opportunities for us in Brazil.

We know Petrobras well, as I told you. For instance, through our participation in Libra where things are going well, we are in a call for tender process for the surface piece, overall the number two, if you consider the early production scheme being one FPSO. And we look forward to build our relation with Petrobras on that.

We will pursue opportunities with Petrobras. We are discussing with them at the moment. The alliance is perfectly fitting our strategic targets. We are building our portfolio on technological strength that we can bring to Petrobras.

And we are, I would – as I repeat, very happy to expand our exposure to Brazil, because not only due to the quality – the high quality of the assets that you can encounter in this country, but also to the fact that we are glad to work with Petrobras, who is I will repeat a good operator and a good company.

And they are Petrobras, getting out of the mess they were facing in the past. And I am glad to see that Petrobras is back to work with a major oil company like us. Let’s talk about the Barnett. Yes, we took this opportunity to preempt 75% from the Barnett. As I recall, you - we own 25% before, which enabled us to preempt the deal.

It has been – this transaction has been negotiated by a third preserve affiliate for more than a year. The terms and conditions were extremely attractive. We believe that this deal is excellent. And it’s rare for me to use this word, excellent. Acquisition is about $500 million. Midstream contract will be restructured.

The Barnett is cash positive now, at less than $2 per MMBtu, end of the year, through this new set of contracts. We will establish a new operating company, basically hiring people coming from Chesapeake and some managers that we will hire from the U.S. market. There will be no expat in this business. And I think that’s basically off.

We are basically hiring from Chesapeake about 150 people to operate this transaction. And this deal is opportunistic and we recognize it. And this new operating company dedicated to the Barnett will be fully dedicated to this asset..

Is there anything you can say on the level of CapEx you expect to spend on that asset over the next year or so?.

Honestly, I don’t know. I have an idea that it will – very limited. Basically that was related to well interventions and some work over to maintain the production, I think. So it’s a limited number, but I don’t have the exact figure for you..

Okay. I will follow with Mike. Thanks..

Thank you very much. Lydia Rainforth from Barclays has our next question..

Thanks and hi Patrick. Two questions, if I could. The first was just on Libya and whether you can give us an update on what Total is seeing there.

And the second one was coming back to the scrip dividend area, given the progress that Total is making on the cost savings and given that downstream margins do seem to have improved a little bit from where we were back in September, is there a scenario you can see where, actually there might be a chance of removing the scrip earlier than if the oil price fall at a price lower than $60? Thanks..

Lydia on your last question, only stupid people doesn’t change their mind, that I recognize that. But on this matter, I will stick on what we said. I agree with you that next year, we see our breakeven after dividend at $55 per barrel. But I maintain my statement that the discounted scrip dividend will be removed at $60 per barrel.

We need some cushion in that matter because we are facing a volatile environment. On Libya offshore, we are operating offshore Al Jurf as usual, normal operation. Offshore, we have had some damages on our assets. So basically – and we have no people on the ground, I would say at the moment. So it’s too early for me to say anything in that matter.

The production overall, in Libya is reported to have increased to about a little less than 600,000 barrels per day, I think. The national oil company has announced 900,000 barrels per day target. This will include the restart of El Sharara field in the south desert, in which Total has a stake.

El Sharara would have represented about 30,000 barrel per day net at plateau. But I have no more to say, I mean, the current situation is difficult to assess. It’s a civil war situation. We noted this positive statement by the national oil company and we will follow closely what they are doing to recover operations on those fields..

That’s great. Thank you..

Thank you. We now have a question from Irene Himona from Societe Generale..

Good afternoon, Patrick. I had two questions, please.

First, on the upstream, with 14 new startups since 2015, can you say roughly what proportion of production is currently PSC, please and has there been a noticeable change in the last sort of couple of years? And then secondly, I know you would never comment on market rumors, but thinking about your targets in the downstream, in marketing in particular of growing and expanding your African sales and market share.

Theoretically, if a set of downstream assets were to become available in South Africa, costing roughly $1 billion, would that be in line with strategic targets in that business? Thank you..

So, your first question about the new project startup and the share of PSC, I would say that basically these people at PSC represent 30% of our contract and that will be applicable also to the new production coming on stream.

So, your other question about downstream, I am not going to comment on press rumor, because if I started to do so, I will spend my time at the phone. We are reviewing every month, I would say, opportunities in the market. Sometime we pursue that like what I mentioned in Tanzania, Kenya and Uganda, sometime we don’t.

This is our own decision and I will not comment further..

Okay, thank you..

Thank you very much. We will now go to our next question from Martijn Rats from Morgan Stanley..

Hi, hello. It’s Martijn. I have only one question left. I wanted to ask you about Iran and my understanding is that you are looking at a large petrochemical project.

And I was wondering what the attraction of that project was?.

Sorry, first I have to apologize, I say thank you to Irene for the last intervention. So, your question about Iran, of course, we are interested in Iran. And once again I repeat, I do not comment on rumor. And I just like to remind you what our CEO said that we look primarily to gathering petrochem projects, but nothing is signed yet.

This is the situation today. We are discussing with Iran. And when there will be some news that we can give to the market, we will give it..

Alright. Thank you..

Thank you. We now have a question from Henry Tarr from Goldman Sachs..

Hi, thanks. The main question was just around CapEx. So I think you have talked about $18 billion for 2016 that implies still a substantial pickup in 4Q to over $5 billion.

I just wondered whether there were sort of specific items coming in 4Q or whether there is an element of prudence to the guidance? And then secondly just to come back maybe on the working capital in the upstream – sorry, this is probably the third question.

But is this primarily related to receivables or inventories and are there kind of specific countries or projects that you are focusing on or is it kind of a broad-based issue? Any color would be great. Thank you..

Your first question about CapEx estimate for fourth quarter, you have to know that and you can see that if you review our figures historically that the fourth quarter tends to be the heaviest quarter in terms of CapEx every year.

So, the $18 billion target takes into account this human behavior of spending more money at the end of the period than at the beginning. The second question was about working capital in the upstream, it’s a broad issue. It’s not only as I said a matter of unpaid amount by national oil companies, both the question of receivable and payable.

So, we can leverage on those two aspects of the working capital and we started to do it. I recognize, as I said, that the $200 million improvement is not enough. But I am sufficiently comfortable to see more benefit of this view that we need to improve this working capital in the fourth quarter. It will improve, I’m sure..

Great, thank you..

Thank you. We will now move to our next question today from Anish Kapadia from Tudor, Pickering, Holt. Please go ahead..

Good afternoon. A couple of questions from me please. Firstly, I was wondering if you could talk a bit about the political and fiscal climate in Nigeria with regards to thinking about sanctioning projects.

You made – you increased the size of one of your discoveries that was announced today and also I think you have another – a number of operated and non-operated projects within Nigeria.

So, just wondering how do you see the political climate, are the fiscal terms attractive enough at the moment to be able to go ahead with projects?.

Yes. You know that basically in Nigeria, we are facing a so-called political issue onshore because of the unrest situation we face onshore within the SPDC joint venture we have with Shell.

It is obvious also for me that Nigeria is a great country and I mean by that, that those people are handling their operation in a manner which prevents people like us to leave the country. So, we are very happy to stay and we will stay. There are some unpaid amounts from NNPC we are not the only one.

We are negotiating and putting in place agreements to recover this money. And I think that’s it for the moment.

I would remind you that in Nigeria, Exxon who is now the operator on the Owowo field that we discovered a few years ago, Exxon drilled another well and completed this well a few days ago and confirmed a potential of a giant field between 500 million and 1 billion barrels according to them, which is comforting our view that we had at the beginning.

And I would say that Owowo is on the same block than Usan. And when we were unable to sell Usan, part of that was due to the fact that we were unable to have recognizing the value of Owowo. And everything is fine now. We had a great asset, a giant field with a good operator. We own, I think, 18% of this field and it will go on.

And I am glad to see that we will be enjoying deflation to sanction this project, which will for sure be sanctionable in the current condition at the moment..

Thank you. I had a quick second question. On the cash flow statement, you have the line of non-current liabilities, valuation allowances and deferred taxes and it’s generally significantly negative.

I just wanted to kind of clarify, is the vast majority of that impacts the deferred tax impacts or are there other kind of significant things in there that you are able to split up?.

Let me take the cash flow statement.

On which page are you of the press release?.

It’s on Page 21, the third line..

Yes. I would say that most of it is deferred taxes, valuation of allowance, for sure. And some non-current liability, I cannot foresee some at the moment, but we will check on that. And Mike will call you back if any non-current liabilities appear on this line..

Thanks very much..

Thank you. We have a question now from Christopher Kuplent from Bank of America/Merrill Lynch..

Hi, good afternoon. Thank you for taking my questions. Two, I will try and keep it short.

Considering your guidance for $55 cash flow breakeven and perhaps exiting from the scrip next year, how do you feel about hybrid bonds? Do you feel any more need of issuing additional hybrid bonds? Do you think that’s an attractive trade-off in this environment or would you argue actually when we exit from the scrip, we also are no longer concerned about our credit rating, our gearing, because we are obviously producing positive free cash flow, and at that stage you wouldn’t want to issue any more hybrid bonds? And the second question, I think it was touched on by a number of people already today is on tax rates.

You have had the few quarters now for the group in the low 20s.

And I wonder, obviously looking back at history, we have been above 50% fairly consistently, how quickly you think we will return there? And to what degree that is linked to $55, $60 oil, thinking about your effective tax rate over a number of years, not looking for any specific guidance? Thank you..

Chris, the first comment I would say on hybrid is that this is very cheap equity. The last 7 non-core – 7-year non-core liability we launched was at a rate of 2.7% a year. And hybrid is one of the two we are using to manage the strength of our balance sheet. And the market offers this opportunity and I will take it.

And honestly, as I used to – the way I used to manage the issuing of bonds or hybrid, I issue when I don’t need the money in a preemptive manner. So, I am not saying that I am going to issue, for sure, any hybrid, but I don’t want to forget about it if there are other opportunities on the market.

Honestly, today, I don’t need to issue for the hybrid, but if the market is mad again, I will take the opportunity. About the tax rate and I fully understand that it is difficult for you guys to forecast our tax rate, not mentioning that last quarter we had, on the upstream, a tax rate of 3%. And now, we are back to 28% in the upstream division.

Just to try and give you some, not guidance but some idea, you can see that on first quarter, our upstream result was just above the breakeven for income when Brent was at $34 per barrel. That was first quarter this year. Of course, the breakeven varies field-by-field, but this is an average.

Basically at $35, you are where most of the fields – or a large part of the fields are at the breakeven in terms of taxes, when you – whenever you are close to the breakeven, the tax rates can change dramatically and that’s why it is difficult to predict.

And I fully recognize that it is difficult for you and your model will be very difficult to run assessing this tax rate. Nevertheless, at $45, $50 per barrel, the burden of the tax at 20% is not very high. So, the effect on the overall net operating income is not big.

Basically, I would say that upstream tax rate could trend back to a more typical level of, let’s say, 40%, maybe 50% percent, at an oil price at $60 per barrel..

Perfect, thank you very much, Patrick. That’s very helpful..

Thank you. We will now move to our next question today from Jon Rigby from UBS. Please go ahead..

Yes, hi, Patrick. I am going to ask a question which I suspect, you haven’t had for a couple of years, which is that it’s to look at your activity rates. And you have talked about ongoing CapEx of $15 billion to $17 billion I think.

So, what is the rate of sanction activity that you need to get to over ‘17 and ‘18 for you to ensure that you are actually spending that level of CapEx? So, you have, obviously, not sanctioned the project for a couple of years, so I am just trying to gauge what the inflection point is going to be and the pace at which your sort of sanctioning and development activity will start to pickup over the next couple of years that’s implied within the CapEx figures that you are giving? Thanks..

$3 billion to $4 billion will be spent in the downstream and gas and renewables, then this leads to $12 billion to $13 billion left for the upstream; $3 billion will be used to resource the new oil, either exploration CapEx for $1 billion or $2 billion for acquisition of resources discovered by others.

We need to spend about $3.5 billion and this is valid under the current cost structure given by the market with the 30% deflation we enjoy, $3.5 billion is needed for maintenance and integrity, which leads to $6.5 billion for growth projects.

So, in aggregate, for growth projects, to renew, let’s say, our production decline and to add 1% to 2% new production, we need to spend $6.5 billion, maybe $7 billion, for growth projects. We will work and sanction world class projects like Libra, like Papua New Guinea, like Uganda.

And do not forget about bond fields, which we are not viable in the previous cost environment, which are now validated. A good example is Zinia, a tieback project, 100 million barrel reserve asset. This asset, Zinia, was not bankable, I would say, 3 years ago. It is now viable and we will sanction it.

So, there will be further development of bond field assets in the future..

Right.

But is it fair to say that we should expect some visibility on further projects emerging, so you start to fill that sort of the 2018 and certainly ‘19 as things like Fort Hills and Yamal and so on begin to fall off the spending?.

Jon, you know we are currently discussing with Iran, we are currently discussing with Brazil. There will be projects coming from both sources of discussion..

Okay. Thanks, Patrick..

Thank you. We will now go to our next question today from Kim Fustier from HSBC. Please go ahead..

Hi, good afternoon, Patrick. I had two questions please. Firstly, I wondered if you could give us a bit of color on the incremental cost reductions given the 10% increase in your cost savings target particularly as it relates to the breakdown between efficiency gains and any other factors.

And then secondly just coming back to Libra in Brazil, could you talk about the progress towards FID on that first FPSO? And from what I have seen, you need to bring the breakeven down to about $35 a barrel and cut costs by about 35% before you sanction the project. Can all of this realistically be achieved by the first half of next year? Thanks..

So Kim, the first question about incremental reduction, we – don’t make my life difficult when I announce that we are increasing our cost cutting target. We were announcing the $2.4 billion cost cutting for 2016 and we are now at $2.7 billion. Most of it is coming from our own work.

There is some limited part of coming from the deflation, but most of it is coming from our own capability to improve our operation. It is true that it looks like as an acceleration of our cost savings. We are working more and more on it.

We recently launched what we call the Total Group shared services, which will provide services through the company’s branches in IT, in human resources, for instance. And this will be a source of new savings in the future. This new organization will be put in place next year.

And just to give you an example, what we did on IT on a limited scale, we saved $100 million last year on IT, thanks to this reorganization that we will continue to implement now on purchasing, on accounting, and so on. Libra FID, there will be several FPSOs on Libra, maybe 4, maybe 5. It seems that we are more inclined to save for today.

We expect the FID for the main FPSO beginning next year. It’s – the FPSO is a grid leader and operator, so the CapEx outlay for us and for Petrobras and for the other partner will be limited. The first FPSO is expected to yield an IRR above 20% at $50 per barrel. And of course, even higher if the oil price goes up.

That’s basically what I can tell you about Libra. And Kim, I would like to remind you that the devaluation of the currency in Brazil may enable us to cut cost further..

Great, thank you..

Thank you. We have no other questions now. I would now like to turn the conference over to Patrick de la Chevardière for his concluding remarks..

Thank you very much all of you to join us today. I repeat the main takeaway messages that I would like to close with. Total is on track to deliver production growth as you see, of more than 4%. And by the meantime, cutting costs more than what we initially thought.

Cash flow is improving and our priority is to continue reducing the breakeven and improving this cash flow. Through active portfolio management and disciplined organic investment, we are building the portfolio on top of that, that we will carry us into the next decade I mentioned even discussion and – discussion in Brazil.

The balance sheet remains strong and we are well positioned to be the most profitable European major oil company. Thank you..