Wednesday, May 15, 2013

UK Budget: Decom Tax Relief Welcomed by Oil, Gas Sector

Osborne To Introduce 'Generous' New UK Shale Gas Tax Regime

Measures announced by the UK Chancellor in his 2013 Budget to guarantee tax relief on the decommissioning of oilfields on the UK Continental Shelf have been welcomed by the UK oil industry.

Oil & Gas UK Chief Executive Malcolm Webb commented in a statement:

"The industry has been working closely with the Treasury since the 2011 Budget to resolve the long-standing problem of uncertainty on decommissioning tax relief. The measures announced today will for the first time ever give companies the certainty they need over the tax treatment of decommissioning.

"At no cost to the Government, it will speed up asset sales and free up capital for companies to use for investment, extending the productive life of the UK continental shelf."

Decom North Sea (DNS), a forum specializing in UK decommissioning, said the new measures will boost the sector by giving increased certainty, in turn leading to new jobs and investment in new technology. DNS pointed out that decommissioning expenditure in the North Sea is forecast to top $1.5 billion (GBP 1 billion) within a few years.

"The Chancellor's confirmation of tax relief through Decommissioning Relief Deeds will help ease one of the greatest concerns facing the North Sea industry and lead to investment and ultimately more jobs," DNS Chief Executive Brian Nixon said.

"Once assets have been recognized as nearing the end of their economic lives, we believe the Budget will lead to operators being able to move forward with their decommissioning plans, which will in turn help to reassure the hundreds of supply chain companies and encourage them to consider investment in new equipment or tooling or to attract new staff."

Meanwhile, Derek Leith – head of oil and gas taxation at Ernst & Young in Aberdeen, Scotland – pointed out that the announcement would act as a gateway to greater investment in the North Sea, creating an active market that is attractive to companies across the oil and gas industry, from super majors to niche operators.

"Cementing the promise of contracts that guarantee tax relief on costs associated with deactivating and dismantling oilfields during the lifetime of this, and future parliaments, removes another layer of fiscal uncertainty from the UK Continental Shelf and should facilitate the transfer of assets," Leith said.

"Smaller companies that had previously been priced out of potential deals will now be in a position to maximise recovery from existing infrastructure, while larger players will be able to free up capital to fund further exploration and production."

In his Budget, the Chancellor also announced that he would introduce a "generous" new tax regime designed to stimulate early investment in the UK's burgeoning shale gas sector.

The new shale gas tax regime will include a field allowance. Meanwhile, new planning guidance on shale gas projects, along with specific proposals to help local communities to benefit from shale drilling, would follow later in 2013, he said.

"Shale gas is part of the future and we will make it happen," Osborne said in his Budget statement to Parliament.

A former engineer, Jon is an award-winning editor who has covered the technology, engineering and energy sectors since the mid-1990s. Email Jon at jmainwaring@rigzone.com.

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Ecopetrol Makes Oil at Pastinaca Well

Ecopetrol S.A. reported that it has proven the presence of heavy crude oil at Pastinaca 1, an exploratory well located within the municipality of Puerto Lopez, Meta Province.

The well is part of the CPO-10 Exploration and Production Agreement of December 18, 2008 between Ecopetrol and the National Hydrocarbons Agency.

Initial tests carried out on the Pastinaca 1 well using an electro-submersible artificial lift, yielded an average crude oil production of 202 barrels of oil per day of 11.7 degrees API (heavy crude) and a water cut of 80 percent. Accumulated production to date is more than 1,448 barrels of oil.

The Pastinaca 1 well is the first hydrocarbons discovery in a well 100-percent owned by Ecopetrol since the beginning of 2013. The Company plans to continue its exploratory activities on block CPO-10 in the months to come.

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Novatek Gets Go-Ahead for Arctic LNG Gas Project

MOSCOW - Russia's largest independent gas producer OAO Novatek said Wednesday it has received environmental approval for a liquefied natural gas project in the Arctic and that construction will begin soon.

Yamal LNG, a joint project with France's Total SA, is expected to produce its first gas at the start of 2017, with output eventually reaching 16.5 million metric tons per year.

Last week, Novatek said it was in advanced talks with a number of potential clients, including China and India on selling LNG supplies from the Arctic project.

Novatek has been banking on Russia's government ending state-controlled OAO Gazprom's monopoly on gas exports and allowing other firms to sell LNG on foreign markets, which are more lucrative than Russia's. Last month, President Vladimir Putin instructed government officials to consider liberalizing exports to boost Russia's share of the global LNG market from 3.6%.

Copyright (c) 2012 Dow Jones & Company, Inc.

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Statoil Gives Go-Ahead to Smorbukk South Extension Project

Statoil reported Wednesday that, along with its partners, it has decided to go ahead with the Smørbukk South Extension project on the Åsgard development, offshore Norway.

The extension holds estimated recoverable reserves of 16.5 million barrels of oil equivalent and will be developed with a new subsea template that will be connected to existing infrastructure in the area.

Recovered gas will be re-injected into the reservoir in order to maintain pressure as oil is drained out of it. The field will be connected to the Åsgard A FPSO installation.

Astrid Helga Jørgenvåg, Statoil's asset owner for Åsgard, commented in a company statement:

"We've matured a profitable project out of a discovery from 1985. Experience from Åsgard operations, existing infrastructure and a bit of patience have contributed to an investment decision for this project.

"In addition we will consider the use of a new well technology that will increase the recovery from this type of reservoir. Smørbukk South Extension is a strategically important project that emphasizes our ambitions to increase recovery from mature areas."

The extension project will use standard equipment, and Statoil has already made investments to minimize the time from project sanction to production start-up, the firm said.

Statoil will now award several contracts for the development, it added.

Drilling operations are planned to begin in early 2015, with production start-up planned for September 2015. Total investments for the project are estimated to be around $595 million.

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Centrica Energy Appoints New Upstream MD

The UK's Centrica Energy announced Tuesday that Sarwjit Sambhi will succeed Jonathan Roger as the managing director of Centrica Energy Upstream at the end of June.

Sambhi is currently Centrica Energy's director of major capital projects and currently oversees development and delivery across the firm's portfolio of exploration and production projects, as well as power projects.

Sambhi commented in a company statement:

"This is an exciting time to be leading Centrica Energy's upstream business. As we integrate our international operations, we will be making major investment decisions which will shape the future of the business and help secure energy supplies for the UK. With a team that includes some of the highest performing individuals in the industry, I have no doubt that the business has a successful future ahead."

Roger has been MD of the upstream unit for three years.

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North Sea's Magnolia Prospect Comes Up Dry

The Magnolia exploration well was drilled to its target depth of approximately 4,920 feet true vertical depth subsea, fulfilling the partners' license obligations.

The well hit its primary targets – the Captain, Corable and Punt sandstones within the Lower Cretaceous interval – but no significant hydrocarbons were encountered, according to Trapoil. The well will now be plugged and abandoned.

The operator of license P1610 is Dana Petroleum, which has a 45-percent interest. Partners in the license include: Summit Petroleum (25 percent), Atlantic Petroleum UK (20 percent) and Trapoil (10 percent). The P1610 license is located to the south and southeast of the producing Captain Field in the Moray Firth and is also close to the Blake and Ross fields.

In February, Trapoil reported that it was buying one third of the Trent East Terrace Area license, located in the southern North Sea, from Perenco UK.

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Petrobras in Talks to Sell Argentine Assets

Petrobras in Talks to Sell Argentine Assets

RIO DE JANEIRO - Brazilian state-run energy giant Petroleo Brasileiro, or Petrobras, is in talks to sell off its Argentine unit as part of a $9.9 billion divestment plan, Chief Executive Maria das Gracas Foster said Tuesday.

Speaking to reporters, Ms. Foster declined to provide any additional details about the talks because of their sensitive nature. Petrobras officials also declined to comment about other assets that the company may have up for sale.

Petrobras, however, has taken its Pasadena Refining System, a refinery located in Pasadena, Texas, off the market, Ms. Foster said. "Pasadena is no longer part of the divestment plan," Ms. Foster said.

Copyright (c) 2012 Dow Jones & Company, Inc.

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Goimar: Mexico's Leading Rig Operator

Goimar: Mexico's Leading Rig Operator

Rigzone conducted an exclusive Q&A with Yann Kirsch, business development and planning director of Goimar, a Mexican service provider for the oil and gas (O&G) industry. Kirsch discusses Goimar's next step in the Mexican energy industry and how their main goal and priority is to assist Petroleos Mexicanos (Pemex) as Mexico's level of crude-oil production decreases

Rigzone: With PEMEX working and exploring deeper depths and requiring specialized skills, what is Goimar doing to fill this need?

Kirsch: Pemex hydrocarbon production has decreased in the last 10 years at an annual average rate of 11 percent. Most hydrocarbon potential in Mexico is in deep water, however shallow water has been, is, and will continue to be the target for its productiveness and economic viability.

Work-over and drilling rigs are facing more challenging tasks in shallow waters, demanding more capabilities to target more complex and deeper jobs. Goimar has been a part of several well-established and reputable companies to address these demanding capabilities by investing in jackup acquisitions with 30,000 feet drilling capacity and 3,000 hp platform (modular) rigs.

In 2010, we hired and partnered with a Houston-based company, Zentech Inc, to design and engineer a 3,000 hp self-erecting modular rig, which will allow Pemex to drill up to 35,000 feet and reduce costs considerably by eliminating the necessity of using a crane barge to install them on the jackets.

Goimar: Mexico's Leading Rig Operator

Rigzone: You mentioned that Goimar is investing a significant amount of money to research and development (R&D) in order to prepare the fields and companies for the deepwater challenge. Can you please explain? And how have recent international events impacted this objective?

Kirsch: Goimar has not only invested money in R&D to develop the GX-10 design (3,000 hp self-erecting modular rig), but has also had several contributions awarded by Mexico's entity in charge of the promotion of scientific and technological activities. The CONACYT (Consejo Nacional de Ciencia y Tecnología / the National Council of Science and Technology) for this design and other development that is currently underway will contribute to the worldwide O&G industry.

Rigzone: What challenges has Goimar experienced when the company shifted its focus to rig owner and manager? What has been the upside?

Kirsch: Goimar transitioned from an operator/manager to rig owner/operator/manager. With our operational experiences and knowledge of Pemex and the O&G industry, we have been able to offer a good return of investment to our investors and shareholders, along with a business experience that minimizes risk and opens new opportunities.

Rigzone: With the North American shale boom occurring and the demand for imports at a 20-year low, how will this affect Mexico, Pemex and Goimar?

Kirsch: This has opened a new range of business opportunities and has awakened interest in many international companies interested in this area. Pemex plans to drill more than 150 wells in the next four years, with a potential investment of around $3 billion.

However, Pemex gas production is not a priority as oil, therefore Pemex will concentrate most of its assets and investments in the oil drilling division - where Goimar's growth has been created.

Rigzone: You mentioned fundamental changes are taking place in the Mexican oil and gas industry that directly affect Pemex's overall growth vision, can you please explain this?

Kirsch: A new presidency has begun, and with it, will come great fundamental changes for the energy sector that will positively affect the current status quo of the Mexican O&G industry.

There is an imminent necessity to boost production, and the only solution to this is hiring more rigs and work as efficiently as possible. This will result directly in an economic and social growth for the country. Pemex has been changing positively in its openness to international players and markets, by creating International Open Tenders, bringing new technology and international know-how. Safety regulations and standards have always been implemented in the industry, and today more than ever, safety procedures and certifications are priority for Pemex.

Rigzone: With PEMEX expanding its shallow water fleet, what opportunities will this provide for Goimar? Pemex is building two jackups at Keppel FELS, will there be an opportunity for Goimar to manage these Pemex-owned units?

Kirsch: Goimar will continue to be one of the leading Mexican rig operator and service providers for Pemex by continuing to acquire jackups. Pemex's interest to build two Keppel FELS units is a positive sign for the Mexican O&G industry, and it will mark an example for international shipyards and increase interest in the Mexican market. This experience will start a new O&M era for Pemex personnel. Pemex will be responsible for operating and maintaining the units.

Rigzone: What are Goimar's near-term goals? Are there more rig acquisitions on the horizon? Does Goimar plan to acquire any deepwater units?

Kirsch: Our main goal is to satisfy our main customer: PEMEX. There will be more rig acquisitions in the short term, and also new builds (jackups and platform rigs). Goimar will not enter the deepwater market, yet.

Rigzone: Do you think Pemex plans to use direct negotiation methods or an open-tender system that was in place before? Can you explain how the current system works and in your opinion, which is more sufficient?

Kirsch: There are two types of methods: open-tender and direct assignation. Both have their pros and cons. It really depends on the current market, timing restraints, players participating, assets availability, rates, and other variables that dictate how Pemex proceeds.

The advantages of a direct assignation (direct negotiation) is that timing is shortened and there are no competitors involved. With an open-tender process, the battle for price and the longer timing on the process is very common.

With more than 10 years of journalism experience, Robin Dupre specializes in the offshore sector of the oil and gas industry. Email Robin at rdupre@rigzone.com.

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Statoil Starts Up Production at Skuld Field

Statoil Starts Up Production at Skuld Field

Statoil reported Monday that production has started at its Skuld field in the Norwegian Sea. According to the firm, Skuld is so far the quickest realized of Statoil's 12 fast-track development projects. It is also the largest of Statoil's fast-track developments.

The Skuld field – which comprises the Fossekall and Dompap discoveries – has recoverable reserves estimated to 90 million barrels of oil equivalent. 90 percent of this its oil with the remainder being gas.

The field will account for more than half of Statoil;s increased production from Norwegian fields where the firm is the operator in 2013. The field is connected to the production vessel Norne, which is also producing for the Norne, Urd, Alve and Marulk fields.

Anita Andersen Stenhaug, Statoil's vice president for the Norne field, commented in a statement:

"Skuld's size makes it stand out in the fast-track portfolio. It could easily have been developed as a stand-alone field. We chose this solution as we saw the opportunity to use the technology and expertise intended for rapid developments, and because we could connect to the existing infrastructure on Norne. This has made it possible to complete the project three years after discovery."

Statoil's fast-track portfolio of projects employ standardized solutions using existing infrastructure rather than building all required infrastructure from scratch.

Stenhaug also pointed out that the field adds several years to the life of the Norne field.

"Skuld will have a very positive impact on Norne's lifetime, which was estimated to 2021 without this addition. We are envisioning production until 2030 at least, and there are opportunities for new activities involving exploration and further development in the Norne area. With the technological development projects we now have underway, we are envisioning opportunities for increased recovery from existing fields," she said.

The average increase in daily production from Skuld over the next two years will be half of what is currently produced to Norne. The field amounts to 45 percent of the added production from Statoil's fast-track projects in 2013, the company said.

Statoil's partners in the Norne field include Eni and Petoro. Statoil holds a 39.1-percent interest, while Petoro and Eni Norge hold 54 percent and 6.9 percent respectively.

The news of the Skurd production start up follows hot on the heels of Statoil's last start-up of a fast-track development, Vigdis, which was announced last week.

A former engineer, Jon is an award-winning editor who has covered the technology, engineering and energy sectors since the mid-1990s. Email Jon at jmainwaring@rigzone.com.

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Total Sells 25% of Tempa Rossa Field to Mitsui

France's Total announced Monday that it is selling a 25-percent interest in the Tempa Rossa field, onshore southern Italy, to Mitsui E&P Italia.

Total will retain a 50-percent holding, as well as operatorship, of the concession, which is located in the Basilicata region. Shell holds the remaining 25 percent.

The Tempa Rossa field is scheduled to come on stream in early 2016, when it is expected to produce 50,000 barrels of oil per day at its peak, as well as 1.4 million cubic feet of gas per day, significantly boosting Italian oil production.

"We are very pleased with this transaction, which further strengthens the ties between Total and Mitsui," Olivier de Langavant, senior vice president for Strategy, Business, Development and R&D at Total, said in a company statement.

"It is another step toward achieving the asset disposal objectives announced by Total for the period 2012-2014."

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