At this time, I would like to welcome everyone to the Fourth Quarter 2016 and Full Year 2016 Ecopetrol Earnings Conference Call. [Operator Instructions] Thank you for your attention. Mrs. Maria Catalina Escobar, Head of Corporate Finance and Investor Relations, will begin the conference today. Mrs. Escobar, you may begin your conference.

Good morning, everyone, and welcome to Ecopetrol's earnings conference call and webcast, in which we will discuss the main financial and operational results of Ecopetrol for the fourth quarter and full year 2016. Before we begin, it is important to mention that the comments in this call by Ecopetrol's senior management can include projections of the company's future performance. These projections do not constitute any commitments of the future results, nor do they take into account risks or uncertainties that could materialize. As a result, Ecopetrol assumes no responsibility in the event that future results are different from the projections shared on this conference call. The call will be led by Mr. Juan Carlos Echeverry, CEO of Ecopetrol. Other participants include Felipe Bayon, COO; Maria Fernanda Suarez, CFO; Max Torres, Exploration Vice President; Hector Manosalva, Vice President of Development and Production; Patricia Zuluaga, Commercialization and Marketing Acting Vice President; Luisa Lafaurie, CEO of Cenit Midstream; Tomas Hernandez, Vice President of Downstream; Raphael Guzman, Technical Vice President; and Carlos Alberto Vargas, Vice President of Transformation. We will begin the presentation with the main achievements of 2016, followed by highlights by business segments and financial results under International Finance Reporting Standards. We will close with the outlook for 2017 and a Q&A session. I now turn the call to Mr. Juan Carlos Echeverry, CEO of Ecopetrol.

Welcome to everyone joining us in this conference call. The Ecopetrol business group's 2016 results demonstrate the company's timely and effective response to the challenges raised by the pricing environment and other events. We ended the year with a company that is transformed operationally, sustainable and financially robust. During the year, Brent reached the lowest levels in the past 12 years with an average of $45 per barrel, 16% below the 2015 price. Although U.S. crude investments remain high, the OPEC agreement to limit oil production uplifted prices in the final quarter of the year. Ecopetrol improved its sales spread from around $12 per barrel to approximately $9 per barrel as a result of its commercial strategy of capturing greater value and the reopening of U.S. market. The volatile price scenario was compounded by significant challenges, such as the peace negotiation process, the border difficulties with Venezuela, El Nino climate phenomenon, the completion of Reficar and the energy project and the tax reform. Let's move onto the next slide to review details of our operational and financial performance during this year. In 2016, EBITDA and EBITDA margin reached solid level of COP 18 trillion and 38%, respectively. The margin was 3 percentage points higher than in 2015 and one of the highest in the oil and gas industry worldwide. Despite experiencing 43,000 barrels less production and lower Brent prices than in 2015, EBITDA remained stable. The group's average production for the year, 718,000 barrels of oil equivalent per day, exceeded in 3,000 barrels the 2016 target. This confirms Ecopetrol's resilience to events such as the closure of the Caño Limón Coveñas oil project, which reduced production in 25,000 barrels per day for 45 days. It also reflects the company's rapid response for adding production in the second half of 2016.…

Thank you, Juan Carlos. During the fourth quarter of the year, we have kept a strict follow-up to the efficiency strategy implemented by the company, incorporating in this period a structural optimization by COP 0.65 trillion for a total of COP 2.24 trillion during 2016. In this way, the accumulated structural efficiencies between 2015 and 2016 have been COP 4.3 trillion. From this, we may highlight the heavy oil dilution strategy, which has contributed by 24% of the total efficiencies. The result of these efficiencies has had a positive effect on the performance of the operational indicators of the greatest impact in each business area of the company, which together, the process improvement is converted into structural efficiencies. An example of this in the upstream operating cost indicator whose improvement are between 10% and 25%. Regarding the segment CapEx, the cost for perforated food has been improved by 44% compared to 2014. Finally, in 2017, Ecopetrol will focus on insuring the sustainability of the efficiencies achieved by 2016, as well as incorporate additional structural efficiencies. With these, I pass it over to Raphael Guzman, who will comment on the result of production.

Thank you, Carlos. In terms of production, 2016 was a challenging year, in which we managed to surpass our annual goal with a production of 718,000 barrels of oil equivalent per day. That is 3,000 barrels per day above the target. Another important milestone was the successful takeover of the operation of both Rubiales and Cusiana Field during the second semester. With this asset, Ecopetrol now directly operates more than 500,000 barrels of oil per day. Even with a drop in prices of close to 20% between 2015 and 2016, the production was only affected by 6% versus the previous year. This reduction is mainly explained by the effect of the reduced investments during the first half of the year. With improvement of prices during the second semester, new investments were approved and executed and allowed Ecopetrol to mitigate the decline rate of some of our fields. This improved the production during the last 2 quarters, including 20,000 barrels of oil equivalent per day in comparison with the second quarter of the year. Also, starting the second half of the year, Ecopetrol America commenced the production of the Gunflint Field, which increased the production of this subsidiary from 3.5 to more than 11,000 barrels of oil equivalent per day. Important fields like Castilla and Chichimene managed to maintain the production, even with the limited investment. In terms of optimization and efficiency, 2016 was a very positive year, where we continue with the materialization of savings with our transformation program, as Carlos just mentioned. As support of this achievement, we would like to highlight the reduction in our lifting cost of about 12% in comparison with 2015, leveraged mainly on the cost reduction of oil services, service maintenance, energy and fluid treatment. Likewise, the components of heavy oil dilution and transport…

Thank you, Raphael. During the fourth quarter, Ecopetrol drilled the wells Boranda and Chimu ST1 1 [ph]. Boranda is located in the block, Playón, and was drilled in association with Parex as operator and with 50% participation of Ecopetrol. At the end of the fourth quarter, the well was under completion operations. The well, Chimu ST1 1 [ph] in the block, Caño Sur, and operated 100% by Ecopetrol, reached a total depth just prior of the end of the year and was plugged and abandoned. The Ecopetrol affiliate, Hocol, drilled the well, Bullerengue Sur, in the block, SSJN1, operated by the company, Lewis, with the participation of 50% Ecopetrol. The well was successful. And the well, Pegaso, located in block, CPO 16, which is 100% Hocol, reached a total depth during December, by the end of the fourth quarter was under evaluation. The well, Payero 1, operated by Equion in the block, Niscota, in the Piedemonte Janeiro, where the participations are Hocol, 20%; Total, 50%; and Repsol, 30%, was declared plugged and abandoned. In the Gulf of Mexico, Ecopetrol America drilled the well, Warrior, situated in the Grand Canyon area of the Gulf of Mexico. Drilling commenced in August and ended during November. Working interest in this project is Ecopetrol America with 20%; JX Nippon Oil & Gas Exploration, 15%; and the operator, Anadarko Petroleum Corporation, was 65%. The well proved the presence of hydrocarbons in several basins, and the well was temporarily plugged and abandoned until development facilities are put in place. By the end of 2016, two projects were being drilled in the Colombian Caribbean offshore, the wells, Purple Angel-1, which is an appraisal well of the Kronos discovery in 2015; and the Gorgon-1, an exploration well. Both wells are operated by Anadarko, 50%, and Ecopetrol as a partner with 50%. These 2 projects will allow assessing the potential of the Colombian offshore with more certainty. Seismic acquisition during the fourth quarter was restricted to the block, YDSN1, which is a 3D seismic program operated by Hocol that acquired 82 square kilometers of seismic. Now Luisa Lafaurie will comment on the midstream results.

Thank you, Max. Good morning. During 2016, we successfully moved forward into two fronts on the midstream business. On one hand, we continue with our cost optimization process, thereby maintaining our cost generation for the group. On the other hand, particularly in the fourth quarter, we focused on promoting the midstream integration process to achieve a more efficient planning process of our operation and maintenance of our infrastructure. Both fronts continue to be our top priority during 2017. From the operating side, the total volume transported during 2016 decreased in 102,000 barrels per day, equivalent to 8.3% less versus 2015, reaching 1.130 million barrels per day. Crude oil volumes transported during 2015 decreased in 11.3% as compared to 2015, mainly due to the lower volumes produced and delivered by our shippers. Out of the total volume of crude transported, approximately 68% belong to Ecopetrol. The total volume of refined product transported through the pipelines increased in 3.7%, mainly as a result of a higher rate of use of the Galán-Sebastopol system to fulfill the demand of product in the central region. Approximately 20% of the total volume transported through the refined product pipelines belong to Ecopetrol. Regarding our investment portfolio, I would like to highlight that we continue performing the activities that will allow us to transport crude oil with higher viscosity to the Coveñas port. In this sense, during 2016, we accomplished our objective to transport crude oil with viscosity over 300 centistokes. In addition, we advanced in the adjustment to our infrastructure in order to transport crude oil of 600 centistokes from the Los Llanos Field to the Coveñas port in a continuous manner. And we also advanced with the investment to put into operation the first blending facilities in Coveñas, which allowed us to deliver crude oil in specific and homogeneous qualities, adding value to our export basket and to our refineries. We expect both initiatives to enter into operation in the second quarter of 2017. Regarding San Fernando-Monterrey project, we complete the construction of the San Fernando pumping station and the five lines that connect the Castilla, Chichimene, San Fernando and Apiay station. During the first quarter of 2017, we expect to begin the filling of tanks and lines. Also, the main activity of Ocensa P135 projects were completed. We are currently working with the Minister of Mines and Energy to obtain the formal authorization in order to begin with our operation of the projects. Finally, I would like to refer to the mid-stream financial results, which were very positive, mainly to the important reductions in our operating and maintenance costs, which allowed us to optimize approximately COP 410 billion in 2016 as compared to 2015. With these, I hand over to Tomas Hernandez, who will comment on the downstream results.

Thanks, Lisa. During the fourth quarter 2016, the Cartagena Refinery stabilization process and unit performance test continued. 21 out of 34 units completed their tests, reaching a 62% progress. The refinery stabilization process will continue until the third quarter 2017, with the completion of the full refinery performance test. Throughout 2016, the Cartagena Refinery was gradually increasing its throughput, reaching an average of 109,000 barrels per day during the startup phase between January and July. During the 2016 stabilization process, between August and December, the refinery reached an average of 128,000 barrels per day with 144,000 barrels per day in December, the highest monthly average since start-up. Upon completion of stabilization and performance tests, the refinery will have an operation at the optimum throughput level. In terms of production, the Cartagena Refinery has gradually increased its high-value product yields, going from an average of 36% during the start-up process to 45% during the stabilization process in middle distillates. In addition, the refinery gross margin has grown from an average of around $3 per barrel to an average of between $8 and $9 per barrel and a peak of $10.5 per barrel during the stabilization phase, maintaining the expectation that the refinery in 2017 will achieve margins in line with market trends for high complexity refineries. The gross margin of the Barrancabermeja refinery in the fourth quarter of 2016 was $14.80 per barrel versus $15 per barrel during the same quarter of 2016. This decrease was mainly due to a more expensive crude slate as a result of higher international crude oil prices. For the full year 2016, the gross margin reached $14 per barrel, $2.8 lower than 2015. This decrease was due to lower product price differentials against crude oil prices, partially offset by higher middle distillate yields, due to the implementation of innovative operational and process improvements, such as the upgrading of a gas oil hydrotreating unit to a mild hydrocracker unit, which increased refinery conversion. In addition, we had the highest production of polyethylene in the history of the refinery, 55,600 tons per year. The throughput of the Barrancabermeja refinery in 2016 was 213,000 barrels per day, decreasing by almost 8,800 barrels per day compared to 2015, due to a heavier crude slate and the scheduled maintenance turnaround of a crude unit in the last quarter of 2016. Now I turn the presentation over to Maria Fernanda Suarez, who will comment on the financial results for the period.

Thank you, Tomas. Good morning, everyone. The solid financial figures we shared today are the result of efforts to strengthen liquidity, achieve structural efficiencies and maintain capital discipline. On average, the Brent crude price was 16% lower compared to 2015, and our investments have to be reduced over 60% that led to a reduction of 43,000 barrels per day in production. Even with a reduction of 8% in revenues, the group was able to reverse the losses posted in 2015 and counts itself among the select group of companies that have earned net profit for the year 2016. The company posted net profit of COP 1.6 trillion, CapEx EBITDA at COP 18 trillion and ended the year with more than COP 14 trillion in available cash. The EBITDA margin increased 3%, reaching 38% for 2016, being one of the higher among the industry. Our commitment to lower leverage was reflected in debt metrics that exceeded initial expectations, achieving our gross debt to EBITDA of 3 times. The net debt-to-EBITDA performed significantly better, declining from 2.6 on 2015 to 2.2 on 2016. Let's move on to the next slide, to look at changes in net profit between 2015 and 2016. In 2015, the company reported a net loss of approximately COP 4 trillion, caused largely by the effect of oil prices forecast over impairments and the negative effect of the peso devaluation. At the end of 2016, Ecopetrol succeeded in reversing that loss and posted a net profit of COP 1.6 trillion. This positive change was made possible due to, first, while revenues decreased COP 4.4 trillion, the cost and expenses decreased COP 4.6 trillion. Our ability to compensate the revenue decline with a cost reduction demonstrates the effective cost control management, austerity measures and higher efficiency across all business segments.…

Thank you, Maria Fernando. Adding reserves and maintaining the pace of production are the company's focus for 2017. Investment in exploration will more than double, and will focus on high-perspective regions. This year reflected in a total of 17 exploratory wells to be drilled vis-a-vis 7 last year. Enhanced recovery technologies will continue adding reserves in mature fields. Our cash position opens up opportunities for inorganic growth. We'll sustain adequate levels of liquidity and will maintain gross debt-to-EBITDA between 2.5 and 3 times. We'll complete Reficar stabilization stage and execute the global performer test in the second half of 2017. The quality and consistency of crudes are important value levers for the business group in order to meet our planning needs. We'll have a new mixing facility at Coveñas. Ecopetrol has once again met the challenges raised by the environment and honored its commitment to operational and financial excellence. The future is encouraging. The 2020 business plan is our navigation map for ensured profitable growth and adding value for our shareholders. We will now open the Q&A session and thank you very much.

[Operator Instructions] We have a question from Mr. Bruno Montanari from Morgan Stanley.

Good morning, good afternoon everyone. Thanks for taking the question. I have a few questions. First one is on the reserve breakdown. Given the different behavior of oil versus gas prices, I was wondering if you could give us the breakdown between oil and gas on the reserves for 2016? My next question is on the outlook for lifting costs in 2017. Although on a year-on-year basis, the performance has been very interesting, we did see an increasing trend of lifting costs throughout 2016. So, I was wondering if that should continue to be the case as we enter this year. And last, you reported a very comfortable cash position on the balance sheet. So, I was wondering if you could elaborate on the uses of cash, either organic or in organic in 2017.

Bruno, hello, this is Raphael Guzman, and thank you for your questions. I will start answering the second question about the lifting cost, while we look for the breakdown on cash and oil. And the short answer is, no, we shouldn't see a continued increase in lifting cost. For the first quarter of 2017, we should see a decrease in cost. The increase you saw from the third quarter to the fourth quarter of 2016 is something that has traditionally happened at Ecopetrol. We do have more expenses at the end of the year, so this is something related with the season and not with structural increases. Other things that helped the increase was - and specifically in this year is that the first two quarters, we had a very restricted cash flow. So we didn't spend much money on the beginning of the year. And we actually, with the improvement of the cash, we didn't spend that at the end of the year. We also did initiatives to increase production like the 25k project that we had at the end of the year. That increased CapEx, but it also increased also the OpEx. So that's why you saw an increase in those two. Okay. The other thing we had, yes, the Rubiales, at the beginning of the year, we didn't have full share of Rubiales. While at the end of the year, we had the full share of Rubiales. And Rubiales comes with an increased OpEx related to the other fields, which also helped increasing the average lifting cost for the quarter. But those things like you see, they are only one-off or seasonal things that should not be a continued increase in OpEx, like the one we saw towards the end of the year.

Hi Bruno, this is Juan Carlos Echeverry. Regarding the use of cash, yes, as you saw in the results, we obtained COP 18 trillion of EBITDA and also COP 14 trillion of cash holdings. Both surpassed our expectations and our guidance. And therefore, we feel that we have a very solid base of cash since we are well aware that a reserves addition is a critical issue for Ecopetrol. It will first increase the amount of money that we dedicate for exploration, will come from $250 million last year to $650 million for exploration. We'll be drilling 17 exploratory wells, 6 of which on the offshore, 1 of those on the Gulf of Mexico and 11 on the onshore in Colombia. And additionally, of course, we'll keep our projects and pilots of enhanced recovery. And especially for this year, and from now on, we will be more active in inorganic growth. So far, we have been conservative in inorganic growth. But from now on, we'll be active in that market. We have - with no hurry in this because we have to be careful that we have the approval of the Board of Directors to seek opportunities in inorganic growth. We're keeping a Pan-American company, but we are open to opportunities in North America, in Mexico, Brazil and all the regions. And we have the cash. Maintaining a very solid basis of cash for the company, we have the resources for this strategy.

Bruno, this is Raphael again. Going back to your first question of the breakdown of reserves, as of the end of 2016, 65% of the reserves were liquid oil and the remaining, gas reserves.

All right. That's very helpful. If I can do one quick follow-up on the inorganic opportunities, does Ecopetrol have any preference for liquids, gas? So which type of asset is your Number 1 choice, if you will?

Yes, Bruno. We have an exposure to heavy oil in onshore. We have growing results in gas in the offshore. Therefore, probably, we will be seeking for balancing in light oil. And also, we could be interested in prospects of probably balancing more our gas holdings. It's true that what we are finding in the Colombian offshore so far is gas. So that presents a good prospect for that balancing. But definitely, we'll be interested in lighter oil than we have on the onshore.

Great. Thank you very much.

Our next question comes from Pavel Molchanov from Raymond James.

Thank you for taking the question guys. Traditionally, a very large portion of your crude exports goes to the U.S. market. And as you know, there is a lot of discussion in Washington about - and a tax on imports, the so-called border adjustment, which would presumably include crude oil. Have you considered what the potential impact of such attacks might be on your U.S. sales business? And has that been incorporated in any of your forecasts?

Thank you, Pavel. Okay, regarding your question, we are currently analyzing different scenarios and the potential impact of such attacks, not only in our exports, but also in our imports of crude oil and exports of crude oil and products. Basically, we have to have in mind that we have an important presence in other markets of Europe and Asia besides the U.S., and that we are very flexible in trying to reach the highest-value markets in for export.

Okay, understood. Can you also comment on what the degree of production disruptions and pipeline outages has been over the past, let's say, 3 to 6 months? I ask because the peace agreement was signed approximately 6 months ago, but we still see frequent headlines about various kinds of attacks against oil industry infrastructure.

Thank you, Pavel. You know that the government is now having these conversations with ELM in Ecuador. These conversations, we hope, will lead ELM to a cease-fire. But so far, they have kept blowing up some parts of our pipeline. This is constrained to probably 100 kilometers of a pipeline. This is a pipeline of 800 kilometers. So it's constrained to an area of 100 kilometers, but nevertheless, is a worrisome development. We are very effective in repairing the pipeline. But for example, today, the pipeline is not operating and the oilfield, Caño Limón, is not pumping up oil. We have not - the impact actually has not been that large. Last year, we had 45 days, in which that oilfield was not pumping. This year, we have had just recently for another week, we have had a stoppage of this oilfield. However, this will be, probably this month, next month, will be more uncertain that the prospect, if something, is positive. We expect at some point that the government reaches a cease-fire with these guys. They have actually proposed a cease-fire. There are conditions from each part of the table. And despite the price on the Caño Limón-Coveñas pipeline, we have produced right last year 3,000 barrels per day more than our target. And this year, actually, we are also above our target. So we have been able to compensate what has happened in the Caño Limón-Coveñas. But nevertheless, it's a worrisome issue, and we'll pay all of our attention to the development in Ecuador and with these guys in that area.

Understood. Thank you very much.

[Operator Instructions] The next question comes from Mr. David Gamboa from TPH.

Hi, good morning. Thanks for taking my questions. I have two questions, please. One of the production guidance for 2017, so we saw how you guys beat your targets slightly last year. You just mentioned that production has been above the target so far this year as well. I'm just wondering, if you have seen any material improvements in the base decline for the company as a whole, how do you see this going forward? If you can provide us with an update on how the base decline is looking and what we can expect from it? That's the first one. The second one, just on your CapEx budget for the year, I wanted to clarify something. So there is a $3.5 billion budget for the year. I understand this number is only CapEx, but when we talk about 2016, at $2.5 billion, that is CapEx, plus some OpEx of some developments that you have. So my question is, what is the cash CapEx that we should expect in the cash flow for 2017? Is it the $3.5 billion? And if this is the case, what would be the guidance for CapEx plus OpEx that we could compare year-on-year with the $2.5 billion that we saw in 2016? Thank you.

Hi. This is Felipe Bayon. Regarding your first question around production guidance for 2017, we're going to be maintaining production around 715,000 barrels. That's both production that we have in-country and production that we have outside of Columbia. And I think that one of the key things to remember here is that we're targeting profitable production and production that's actually providing us with good margin. So in that sense, we will try to achieve the 715,000 barrels. That is our guidance. In terms of base decline, I'd say that our main fields are actually producing very well and are actually behaving very well in terms of not only the results that we're seeing from infill drilling, and we're being able to manage that decline, but also in terms of some of the enhanced oil recovery and the pilots that we were describing earlier in our presentation. So we're actually very comfortable with the performance of the fields in terms of base decline. In terms of your second question, which is the level of CapEx and the cash CapEx as such, you need to compare the $2.5 billion that we actually spend in 2016 versus $3.5 billion that we have put in our budget as the CapEx for 2017. So all of this is actually investment CapEx. In terms of the OpEx, we're envisaging that we should be around an average of around $7 per barrel in terms of lifting cost. And that's sort of the range where we see ourselves in 2017.

Hi David good morning. Thank you for the question. Well, regarding CapEx budget, it's going to be $3.5 billion. As you mentioned, on 2016, it was around $2.5 billion. I can do a follow-up call with you. But really, on those numbers, we are targeting on CapEx. What you see, the effect on the cash flow, is the effect of the real execution or the difference of working capital of the accounts receivables. Because one thing that we account for is how much we've already have executed, and the difference on the cash flow is just how much have we already paid. That's the only difference that you see between what we target and what you see on the cash flow. For 2017, it will be $3.5 billion of CapEx. And on the cash flow, you should see the total effect, unless there are things that are not executed on 2017 or that we will have accounts to be paid during 2018. But that is the movement of the working capital. And if you want, we can do a follow-on question on that for more clarity.

Okay, thank you very much.

Thank you very much. Thank you to you all for participating in this conference call. I want to emphasize the fact that the metrics that we chose for 2016 performance were surpassed. We all aim to surpass expectations, and that was the case of reduction in costs on improvement in productivity and efficiencies. It was also the fact that there have been an integrated group helped a lot during the year. We saw the segments of the midstream and downstream coming up very timely to compensate the difficulties that were derived from the decline in price of oil in the upstream. We also saw an over-performance in cash and over-performance in EBITDA. And that leads to a new interesting 2017, in which we see the addition of reserves as a key issue. Therefore, exploration now is probably in the driving wheel. We have to add reserves by giving more resources to exploration; second, enhance recovery in our mature fields; and third, of course, the new activity in inorganic growth. So with these, we expect to have covered most of the issues. Thank you very much for participating in this conference call and for your follow-up, your serious follow-up of our numbers of the evolution of our group. Thank you to you all, and have a good day.

This concludes today's conference call. Thank you for participating. You may now disconnect.