Good morning. And welcome to the GeoPark Limited Conference Call following the results announcement for the Second Quarter Ended June 30, 2015. At this time, all participants are in a listen-only mode. A question-and-answer session will follow the formal presentation. [Operator Instructions] If you do not have a copy of the press release, please call Grayling in New York at +1 (646) 284-9400 and we will have one sent to you. Alternatively, you may obtain a copy of the release at the Investor Support section on the company's corporate website at www.geo-park.com. A replay of today's call maybe accessed by dialing in on the numbers provided in the press release or by accessing the webcast in the Investor Support section of the GeoPark corporate website. Before we continue, please note that certain statements contained in the results release and on this conference call are forward-looking statements rather than historical facts and are subject to risks and uncertainties that could cause actual results to differ materially from those described. With respect to such forward-looking statements the company seeks protection afforded by the Private Securities Litigation Reform Act of 1995. These risks include a variety of factors, including competitive developments and risk factors listed from time-to-time in the company's SEC reports and public releases. Those risks are intended to identify certain principle factors that could cause actual results to differ materially from those described in the forward-looking statements, but are not intended to represent a complete risk of the company’s business. All financial figures included herein were prepared in accordance to IFRS and are stated in U.S. dollars unless otherwise noted. Reserves figures correspond to PRMS standards. On the call today call from GeoPark is James F. Park, Chief Executive Officer; Augusto Zubillaga, Chief Operating Officer; and Andrés Ocampo, Chief Financial Officer; and Pablo Ducci, Capital Markets Director. And now, I’ll turn the call over to James Park. Mr. Park you may begin.

Thank you, and good morning, everyone. In December last year, GeoPark quickly move to adjust our work programs, investments and cost structure to prepare for and accommodate a sustain period of lower oil prices in the $45 to $50 per barrel range. Our strong performance during the second quarter reflects these decisive actions. Our overall cash cost made up of production, operating, G&G, G&A and selling costs were reduced by 38%. Capital expenditures were cut back by 84%. Cash in hand increased to $105 million and overall production has been generally maintained. These efforts are ongoing and continued to generate new lower cost growth opportunities. We are also pleased to be back drilling again, which we will continue for the remainder of the year. Importantly, our successful drilling program on the Llanos 34 block in Colombia has been resumed and already with some good indications. The Llanos 34 block operated by GeoPark represents the strongest growth story in the Colombian oil industry in the last two years. Our success in preserving cash and effectively allocating capital also demonstrate the underlying strength and diversity of our rich asset platform. In addition to our certified 122 million barrel that discovered 2P oil and gas reserves valued at $1.7 billion, an independent audit of our exploration resources were conducted and identified a potential of 770 million to 1.5 barrels of oil equivalent. These are resources located in proven hydrocarbon basins managed by an experience team with a strong regional track record and a 70% historical drilling success rate. And while continuing develop our organic assets, we also remained active in the search for an acquisition of new exceptional shareholder value adding projects, with our main focus on divestments by national oil companies, corporate M&A opportunity and individual attractive low cost bolt-on assets. With GeoPark’s existing five-country platform and operating teams, we have a wide universe of viable and attractive acquisition opportunities. In this regard, we are pleased to partner again with Wintershall, Germany’s largest oil and gas producer on a new high potential low-cost block in the Neuquen Basin, which is a good strategic fit to our portfolio with respect to geology, potential cost and timing. We also would like to thank GeoPark’s team for its professionalism and heart and which again is creating result in positioning us to continue on our nine-year track record of growth. Thank you and let’s please turn to Zubi for operational highlights.

Okay. Thanks, Jim and good morning to everyone. Let’s please focus on three main operational pillars, production, cost optimization and drilling. One, due to the second quarter, oil and gas production averaged 19,500 barrel of oil per day led by continued production growth in Colombia along with a favorable production in Brazil and decline in production in Chile. This was impacted by no new wells been drilled in during the first half of the year. Two, on cost optimization, our team have adjusted our entire cost structure across the board with meaningful results. Our work programs and investments have been reduced by over 80% and our product and operating cost have been reduced by over 40%. This have opened up new some opportunities such as we started the profitable operation of projecting La Cuerva oilfield in Colombia after redesigning the operation due to reduced operating cost by over 50%. Our drilling cost have also been reduced by over 20% which allowed us to generate attractive returns with payout ratios between 8 to 12 months for our drilling program this year, even at $45 to $50 per barrel oil prices. As we -- drilling restarted in June with the drilling of two new exploration prospects. Electric log from the Chachalaca 1 well in Llanos 34 indicate the presence of hydrocarbons in both Mirador and Guadalupe formations. We will continue drilling for the remainder of the year with addition of another five to six wells in Colombia, representing our mix of exploration and development wells. And currently, we are drilling [Ghana I] [ph]. For other activities worth noting during the quarter include, in Chile -- in Chile, we’ve gas field in Tierra del Fuego was full on production and also the treatment plant for the Ache gas field in the Fell Block…

[Operator Instructions] Our first question comes from the line of Diego Mendes with Itau. Please go ahead with your question.

Hi, guys. Good morning. So I have two main questions. The first one is regarding our strategy for the last year. What are thinking that you’re going to do if oil prices remain more or less where they are today? So would you still continue drilling in Colombia, but what could happen to Chile and to Peru? And also, if you could provide the updates on what is happening on the Tierra del Fuego, if there was any involvement in the study there and also indicators of Peru if we’re able to sign the new contract with Petroperu? Thank you.

So thank you, Diego. As far as our so -- when we first back in December we decided the plan for two years of this low oil price, so really said everything in motion for a period of low oil prices for the next two years. As part of our capital allocation program, the way we look at projects, all our business units from this project for our budgets and we rank those based on economic, technical, and strategic reasons to really determine what the program is. The great success that we have been having in Colombia was Tigana and Tua fields make those attractive programs. So we probably could expect that a lot of the capital would go towards the development and expansion of those particular fields. With respect to Tierra del Fuego, we are actually having a meeting on that right after this call with our team from Chile. So well that’s an ongoing process and we can answer that little better next call.

This quarter we were able to put on production a new field in Tierra del Fuego at Chile with gas field, that’s what we mentioned in the interaction. And lastly, on the Peru question, we haven’t yet closed the acquisition there. We are still pending to a certain degree. We expect that to come during September. We continue working with the government entities to provide information necessary to get that process finished as soon as developed.

Okay. Thank you. And just last question, what is the production expectations for the first quarter coming from the Ache field in Chile?

The Ache -- hi Diego. Zubi here. Well, the Ache field is going to be an important production in October. So we are -- that we are going to full on production between 200 to 250 cubic meters a day of that -- thousand, I’m sorry, 200,000 cubic meters a day.

Okay. Thank you very much.

Thank you. [Operator Instructions] Our next question comes from the line of Andrés Cardona. Please go ahead with your question. Andrés Cardona: Hey, James. It’s Andrés Cardona. Just a quick question of La Cuerva, how much production are you expecting from this field now there [indiscernible]? Andrés Ocampo: Hi, Andrés. Andrés here. We were on production on this field in July and so we started with 600 barrel of oil per day and we are estimating to reach a production of 800 barrel of oil per day at the end of this month. Andrés Cardona: Cool. Thank you, guys.

Thank you. [Operator Instructions] Our next question comes from the line of Daniel Lerner with CarVal Investors. Please go ahead with your question.

Hi. Good morning, guys. Can you hear me all right?

Very good. Hi, Daniel.

Hi. How are you? Just a quick question, just to get an idea of the cost reductions that you’ve been able to implement. Can you give us any guidance as to how much of that is nominal price reduction as opposed to the assistance of a depreciated currency in your markets? Just trying to get an idea of how much the currency helping you versus just real like-for-like cost reduction, any possibility on giving us guidance there? Andrés Ocampo: Yes. On a consolidated basis approaching at 60% of our base cost are nominated in local currencies. So the impact of -- in this quarter the impact of the evaluation is approaching at the 40% to 50% of the cost reductions and the rest is basic reductions or making the operations more efficient. That’s both apart from the figures.

Okay. Thank you.

Thank you. [Operator Instructions] Our next question comes from the line of Jamie Somerville with TD Securities. Please go ahead with your question.

Hi. Good morning. Thanks for the call and thanks for taking my question. A couple of questions on peripheral assets here, coming back to La Cuerva. So you reduced the OpEx by 50%? I think you’ve just clarified that about half of that is coming from the FX rate? Can you clarify what the rest is coming from? Is it lower transportation costs? What exactly is it? And maybe I’ll follow that up with -- when you made the decision to put this asset back on stream where oil price is higher and you’re actually achieving reasonably net backs with the decline in oil price that we’ve seen over the last couple of months since June? Andrés Ocampo: Hi, Jamie, and thank you for your question. Yes. It was reduced by 50%, that’s a combination of OpEx there, probably in the case the 50% is driven by depreciation on a consolidated basis, in the case of La Cuerva higher the impact of really signing the operation. La Cuerva is a block that has the number of wells and having inside growth. So basically we pull it back on with fewer wells producing with the most efficient wells on production and that’s why the production is going to be around 800 apposed to 1200 when it was started originally. We also reduced the transportation cost significantly, the road mines announced significantly. The headcount of the people working on the field has also been reduced significantly. We change the fuel for running the energy for generating the energy in the fuel, which also reduced the cost a lot and that allowed us to pull it back on production and make it generate positive cash flow at $45 to $50 oil price which is what we are using for the whole year.

Okay. Thank you. And then just, can you clarify with the Argentina deal that $5 million amount is that what you expect to spend at 100% for these two wells to carry themselves through this first two wells or is that there are spending cap there? Andrés Ocampo: Yes. That’s what we expect to spend on cost of the wells.

Okay. And can you talk strategically your interest in Argentina, interesting that kind of you have overhead in Argentina, so there is maybe tax reason to have production in Argentina that you are doing there an exploration form. Is that strategically positioning yourself to be in Argentina when things potential change through the elections or how do you think about Argentina specifically? Andrés Ocampo: Okay. Yes. One of the reasons we have a big corporate office here in Argentina, we always and our team knows all the basins here very well. We did already projects in Argentina for many years, never found the right one or the good one for us to participate. In this case, our technical team presented this project being one of the most attractive conventional place is the Neuquen Basin with some unconventional upside as well. It also used in partnership with the good operator, as Wintershall. And yes, for us, it makes sense to have some production in Argentina because we have a corporate office here. The commitment is modest and is exactly in time. So it’s not until the end of next year that we have to put capital in it. And also, we have very good prospects with very high chances of success, very hard through, was very positive about them, and that’s why we decided to move in.

Thank you very much.

[Operator Instructions] And it seems we have no further questions at this time. I’d like to turn the floor back to Mr. Jim Park for closing remarks.

Thank you all, again, for joining today to review our performance and opportunities in 2015. Please do not hesitate to contact us if you have any questions. Thank you.

Thank you. This concludes today's teleconference. You may disconnect your lines at this time. And thank you for your participation.