The Top 10 Private Oil & Gas Companies in Alberta

Posted by Jonathan Moore

Sep 29, 2016 5:01:40 AM

Analysis using CanOils Assets shows that private companies oversaw around 330,000 boe/d of production in Alberta in July 2016, 74% of which was natural gas. To put this into perspective, this is almost six times the volume produced by private companies operating in B.C. in the same month (see note 1).

Download a map of Alberta’s Top 10 private companies’ operated wells here

AB_Priv_Co_Graph1_Jul2016.jpg

Source: CanOils Assets - find out more

Of these companies, Ember Resources Inc. is the single largest private operator with more than 53,000 boe/d in July 2016. Ember is owned by a consortium of investors including Brookfield Asset Management. The company’s assets are mainly located in the PSAC regions of Southeastern Alberta (AB3) and Central Alberta (AB5) and are nearly entirely comprised of natural gas wells. The second largest producer, Jupiter Resources Inc., is also backed by an investment firm, Apollo Global Management, and operated 36,500 boe/d of production in July 2016.

The company with the largest diversification in terms of the location of its operated wells is China-backed Calgary Sinoenergy Investment Corp., which operates around 24,000 boe/d after the completion of its Cdn$770 million acquisition of Long Run Exploration Ltd. in June 2016. The company operates wells in five PSAC regions in Alberta.

Download a map of Alberta’s Top 10 private companies’ operated wells here

AB_Priv_Co_Graph__Table_Jul20162.jpg

Source: CanOils Assets - find out more

For more on private oil and gas companies in British Columbia, click here.

Notes

1) “Production” in this article refers to operated production, rather than working interest production. CanOils Assets does also include working interest production estimates for every company with an ownership stake in a producing well in Canada, but this article only focuses on production from wells where each company is listed in government data as the operator.

2) All data included in this article is sourced from CanOils Assets. Find out more about CanOils Assets here.

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Why Europe is pivotal to LNG growth

Posted by Paul Harris

Sep 22, 2016 8:57:27 AM

Europe will play a pivotal role in the performance of LNG markets globally amid ongoing concerns over gas over-supply, reduced demand in some quarters and pressure on prices.

The major question remains the extent to which Europe can absorb increased gas volumes as part of goals to de-carbonize economies, promote renewables, ensure pricing remain competitive, safeguard energy security and deliver diversity of supply.

Monika Zsigri, an energy policy officer with the European Commission, confirmed that as EU domestic gas production decreased, net EU gas imports increased by 11% last year. LNG shipments bound for Europe rose 6%, as did LNG’s share of the imported gas mix, to 13%.

Qatar remains the largest supplier of LNG to Europe, with a 56% market share, followed by Algeria and Nigeria. While the direct impact of U.S. LNG has not been significant in Europe, it is putting downward pressure on prices. “There is a lot of gas in the market, and the market is fairly flat in Asia,” Zsigri said at the LNGgc Conference in London this week.

LNG import capacities are set to increase dramatically in several European countries by 2025, notably in the United Kingdom, France, Ukraine, Poland, Greece and Croatia, according to Evaluate Energy data.

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Source: Evaluate Energy (see note 1)

Costanza Jacazio, a senior gas analyst at the International Energy Authority, expects demand to stabilize in Europe followed by a gradual recovery due in part to retiring coal and nuclear plants. But she said the global rebalancing of markets would depend on the pace of expansion in China, together with other developing Asian nations.

“Japan and Korea will play a much less important role in absorbing new LNG production coming onto the market [in the next five years],” she said. “This means the rest of the world needs to take this incremental LNG.”

Carmen Lopez-Contreras, a senior analyst on Repsol’s gas and power team, said declining European power production (for example in the United Kingdom and the Netherlands) and the need to retain gas supplies while countries adopt more renewable energy solutions will bolster gas demand.

“We have a lot of new volumes coming on-stream,” she said. “Demand has not coped with our expectations. Traditional buyers [like Japan and Korea] have not demanded as much LNG as we are used to. They have turned to coal, which is cheaper. Right now we are at the very bottom of gas prices, but this is incentivizing demand.”

Pricing, volume and destination flexibility will be high on the agenda for buyers facing greater uncertainty and volatility in demand.

"It is very likely markets will struggle to absorb incremental supplies," said Armelle Lecarpentier, chief economist, CEDIGAZ, the international association for natural gas.

She believes the United States is on track to take the role of swing supplier, adding that the trajectory of global gas markets, and the pace of any market rebalancing, will rest strongly on demand in China and developing Asian nations. She sees this flexible LNG going to new importers in South East Asia, South Asia, North Africa and Latin America. She feels the rise of renewables and increased energy efficiency will temper additional European demand.

Notes

1) Proposed import capacity for end 2025 is calculated assuming that all currently active import terminals remain in operation and all proposed projects, regardless of current status, reach completion at their respectively scheduled onstream dates.

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The Top 10 Private Oil & Gas Companies in British Columbia

Posted by Jonathan Moore

Sep 20, 2016 8:10:17 AM

Analysis using CanOils Assets shows that production from private operators in British Columbia has increased by 76% within one year, based on July production figures. In July 2016, private companies were the operators of just over 56,000 boe/d, compared to 32,000 boe/d a year earlier.

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Source: CanOils Assets – find out more here.

The biggest private producers – based on operated production – are located in the areas of the Montney. This is perhaps unsurprising given the surge in activity over the past few years within the areas of one of Canada’s premier plays. A detailed map showing the locations of each of the private company’s operated wells in British Columbia as well as their individual year-on-year production increases and their wells’ location in relation to major British Columbia basins, can be downloaded for free here.

Canbriam Energy Inc., is British Columbia’s largest private producer, based on operated production as of July 31, 2016. The company operates in the Altares region of the Montney, and its operated wells produce around 22,300 boe/d. Every other private producer that operates volumes of over 1,000 boe/d is also located in the area of the Montney, apart from GS E&R, a South Korea-backed entity with 1,500 boe/d in the Liard Basin.

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Source: CanOils Assets – find out more here.

Download Now: Map and Detailed Private Company Data in British Columbia

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More Montney assets hit market in wake of Seven Generations’ Cdn$1.9bn deal

Posted by Eoin Coyne

Sep 8, 2016 4:39:32 AM

Two Canadian producers are seeking to capitalize on the enduring pulling power of the Montney play by putting assets up for sale, according to CanOils’ newest report focused on M&A activity in August.

RMP Energy Inc. (TSX:RMP) and Chinook Energy Inc. (TSX:CKE) have healthy balance sheets and a good inventory of development assets. Both have extensive holdings in the Montney shale. They form the bedrock of the total 12,700 boe/d of publicly disclosed Canadian assets put up for sale in August 2016. The listings follow the recent Cdn$1.9 billion acquisition by Seven Generations Energy Ltd.’s (TSX:VII) of predominantly Montney assets from Paramount Resources Ltd (TSX:POU), which showed Montney assets can still attract strong interest for high value deals.

RMP Energy Inc.

The largest Canadian asset listing in August involved RMP Energy initiating a strategic alternatives process, retaining Scotia Waterous and FirstEnergy Capital Corp. The majority of RMP’s production is derived from the Ante Creek and Waskahigan fields. RMP produces 8,425 boe/d (43% liquids) based on Q2 2016 production figures. The company owns 24.6 million boe of 1P reserves (36% liquids).

Active RMP Energy Inc. wells as of July 31, 2016

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Source: CanOils Monthly M&A Review, August 2016

Chinook Energy Inc.

Chinook Energy Inc. has also initiated a strategic alternatives review and has retained Peters & Co. as its exclusive financial advisor. Chinook is predominantly Montney-focused with 2,890 boe/d of production during Q2 2016 and 12.9 million boe (16% liquids) of 1P reserves. Chinook said it is open to expanding its core operations via acquisitions or by establishing a new core of operations. They will also entertain a merger, sale or JV with a well-capitalized entity to help develop existing assets.

Also this month...

Away from the Montney, August saw Virginia Hills Oil Corp. (TSX-V:VHO) initiate its own strategic review process, while Grant Thornton, in its role as receiver for RedWater Energy Corp., retained CB Securities to advise in the sale of a portion of RedWater’s assets.

Full details on all of these assets up for sale, as well as a detailed look into all of August’s biggest M&A stories, can be found in CanOils’ latest monthly M&A review of the Canadian E&P industry, which is available for download now.

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Top 5 Upstream M&A Deals in Canada in 2016 So Far

Posted by Mark Young

Aug 16, 2016 7:24:48 AM

The opening seven months of 2016 have brought a revival in the Canadian E&P space following an extremely lacklustre end to 2015, when very few deals were agreed in light of an uncertain and inhibitive pricing environment.

In CanOils latest monthly review of deals in the Canadian E&P space, the largest single deal of the year so far is featured – the full report can be downloaded at this link.

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Source: CanOils Monthly M&A Review, July 2016

The deal saw Seven Generations Energy Ltd. (TSX:VII) agree to acquire Montney production and lands from Paramount Resources Ltd. (TSX:POU) for Cdn$1.9 billion. This consideration represents the biggest deal in Canada since Suncor Energy Inc.’s (TSX:SU) acquisition of Syncrude partner Canadian Oil Sands Ltd. in late 2015. The top 5 deals in the Canadian upstream space between January and July 2016 are briefly profiled below:

1 – Seven Generations Energy acquires Montney assets from Paramount Resources

The consideration of Cdn$1.9 billion will be made up of Cdn$475 million in cash, 33.5 million Seven Generation shares and the assumption of around Cdn$584 million of Paramount debt. By acquiring these assets, Seven Generations is boosting its portfolio with a further 199 million boe of 1P reserves, 30,000 boe/d of production in the company’s core Kakwa River area and 155 net sections of Montney land.

CanOils Assets map of the Kakwa River area as of June 30, 2016

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Source: CanOils Monthly M&A Review, July 2016 - Click Here for Map Legend of wells

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2 – Teine Energy acquires Penn West Petroleum’s Saskatchewan assets

Teine Energy Ltd., with funds from its own existing credit facilities and significant financial backing from the Canada Pension Plan Investment Board, acquired Penn West Petroleum Ltd.’s (TSX:PWT) Dodsland Viking assets in Saskatchewan for Cdn$975 million.

Since Q4 2014, when the price downturn really began, Penn West has sold assets in deals worth a total of Cdn$2.5 billion, all aimed at reducing total debt. This single Cdn$975 million asset sale results in a markedly improved capital structure; Penn West now says that the company is in the top tier of its peers in terms of all significant debt metrics.

3 – Suncor Energy buys Murphy Oil out of Syncrude

Suncor Energy Inc. (TSX:SU), following the Cdn$6.6 billion deal to acquire Canadian Oil Sands Ltd. at the start of 2016, increased its stake in Syncrude by a further 5% in June when it completed its Cdn$937 million deal with Murphy Oil Corp. (NYSE:MUR). This now means that Suncor’s stake in the Syncrude project is 53.74%. Murphy Oil had been a participant in the Syncrude project for over 22 years.

4 – Birchcliff Energy acquires Encana’s Gordondale assets in Alberta

Encana Corp. (TSX:ECA), after making two asset sales of over Cdn$1 billion in the United States in the latter half of 2015, has now completed a significant asset sale in Canada. Birchcliff Energy Ltd. (TSX:BIR) is the acquirer and has parted with Cdn$625 million for Encana’s wells and leases in the Gordondale area of Alberta. The assets (65% gas weighted) are located in the Peace River Arch region and the target formations are the Montney and Doig resource plays.

CanOils Assets map of operated BIR/ECA leases in Gordondale area

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Source: CanOils Monthly M&A Review, July 2016 - Click Here for Map Legend of wells - These leases are located just south of Pouce Coupe on the AB/BC Border.

5 – Whitecap Resources acquires southwest Saskatchewan assets from Husky Energy

Whitecap Resources Inc. (TSX:WCP) acquired assets in southeast Saskatchewan from Husky Energy Inc. (TSX:HSE) for Cdn$595 million. The deal increased Whitecap’s production by 11,600 boe/d and also increased the company’s oil weighting by 3% to 79%, as the assets being acquired produce 98% oil and NGLs.

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Do We Need to Re-think UK Energy Policy?

Posted by Paul Harris

Jul 26, 2016 3:30:00 AM

New inquiry to examine technologies and pricing

The future shape of the UK’s energy market – including sources of domestic supply and pricing strategies – is subject to a new inquiry launched last week.

Led by the House of Lords Economic Affairs Committee, the inquiry will assess whether a combination of policy and subsidies have led to failures in the energy market, and what new action may be needed.

“Coal power stations are being closed and old nuclear stations are coming towards the end of their life,” said committee chair Lord Hollick. “But it is not clear how they will be replaced and at what cost.”

The inquiry centres on the premise that UK energy policy over the last decade has focused on three objectives: maintaining supply and minimizing threats to energy security; keeping supply costs competitive for businesses and consumers users; and, de-carbonization, sought primarily by closing coal-fired plants and offering subsidies to renewable energy infrastructure.

According to a House of Lords release yesterday, a report by the committee two years ago into the economic impact on UK energy policy of shale gas and oil concluded that there had been a lack of clarity and consistency in energy policy over many years.

“This failure of policy had left the UK dangerously close to lacking sufficient electricity generating capacity,” said Lord Hollick. “Over two years later, little has changed.”

The UK, with its history of offshore production, was a net exporter of oil, natural gas liquids and gas until 2005. Since that time, the UK has been reliant on overseas imports to meet domestic demand.

UK_OG_Measures_July_2016_2.jpg

Data from our Evaluate Energy team confirms that in the past decade that disparity has been greatest in 2013, when the UK imported 1.2 million boe/d more than it exported. In 2015, that figure was 1.05 million boe/d.

UK oil/NGL/gas production has declined every year since 2000, when it stood at 4.45 million boe/d, to 1.44 million boe/d in 2014. It increased slightly in 2015, to 1.6 million boe/d.

The committee will seek to identify emerging technologies that could materially alter the UK energy market over the next decade and beyond.

This will likely include discussion over the role played by on-shore shale gas and other alternatives. Earlier this year, former UK energy minister Andrea Leadsom described shale gas as an effective potential “bridging fuel” amid goals to reduce reliance on coal while seeking alternative future power supplies. She viewed shale as a homegrown solution that could create thousands of jobs during development and production. 

Lord Hollick added: “The energy market involves an extraordinarily complicated mix of policy interventions and subsidies. Every investment in electricity generating supply is effectively determined by the government. This inquiry will seek to investigate whether current policy is delivering the best deal for energy users and whether it is striking the correct balance between private and public sector involvement."

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Brexit latest: Disentangling energy policy after UK votes to leave EU

Posted by Paul Harris

Jul 20, 2016 4:56:14 AM

UK energy policy has become rather entangled in the dramatic reorganization of government that has taken place since the nation opted out of the European Union.

It’s barely a week since Theresa May became the new leader of the Conservative party, and by extension the new Prime Minister.

By all accounts, she’s settled in quickly: a major cabinet reshuffle involving major (and controversial) new roles for Brexit campaigners, early talks with Scotland’s first minister in view of Scotland’s significant pro-EU support, and preparations for meetings with German and French leaders this week.

She’s also found time to replace the Department of Energy and Climate Change (DECC) with a larger, more extensive and over-arching Department for Business, Energy and Industrial Strategy (BEIS).

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There are two broad schools of thought about whether the switch is a good thing. One is that it is sensible to tie the energy needs of the country ever more tightly with business and industrial development. The flip side is concern that climate change – as an agenda issue – will slide down the priority list, subsumed by pressing business and industrial growth demands.

The creation of the new BEIS department has divided opinion between political groups and environmentalists.

Greg Clark will lead the new department. Under the reshuffle, government energy lead (and recent contender for Prime Minister) Andrea Leadsom becomes environment secretary.

Prime Minister May gave us some clues to her energy priorities at the launch of her national campaign to become Tory leader last week, where she spoke of the need for an energy policy “that emphasizes the reliability of supply and lower costs for users.”

The UK, with its history of offshore production, was a net exporter of oil, natural gas liquids and gas until 2005.

Since that time, however, the UK has been reliant on overseas imports to meet energy needs.

Data from our Evaluate Energy team confirms that in the past decade that disparity has been greatest in 2013, when the UK imported 1.2 million boe/d more than it exported. In 2015, that figure was down slightly, at 1.05 million boe/d.

Overall UK consumption of oil/NGL/gas peaked in 2005, at 3.5 million boe/d. It has declined virtually every year since, and stood at 2.6 million boe/d in 2015.

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Source: Evaluate Energy

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Source: Evaluate Energy

Meanwhile, our data confirms that UK oil/NGL/gas production has declined every year since 2000, when it stood at 4.45 million boe/d, to 1.44 million boe/d in 2014. It increased slightly in 2015, to 1.6 million boe/d.

Prime Minister May’s tone feels very much in tune with the former DECC list of energy priorities, where security of domestic energy supply ranked very high indeed.

Earlier this year, as energy minister, Leadsom reinforced the need for UK energy security. She was addressing the Shale World UK conference, which focused upon the potential for on-shore UK shale gas.

Leadsom positioned shale gas as an “effective low-carbon bridge” amid broader goals to reduce the nation’s reliance upon coal and secure alternative future power supplies. She viewed shale as a homegrown solution that would in turn create many thousands of jobs during development and ongoing production phases. 

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Canadian Upstream Oil & Gas M&A Finally Takes Off Again in June 2016

Posted by Mark Young

Jul 13, 2016 4:47:27 AM

In June 2016, the total value of announced M&A deals in the Canadian E&P sector totalled Cdn$2.7 billion, according to CanOils' new report that looks at all upstream deals involving Canadian E&P companies in June. This resurgence in value comes on the back of an upward trending WTI oil price that surpassed US$50 per barrel during the month. 

Despite the fact that June saw Canada's biggest upstream deal in the first six months of 2016, the overall deal value of Cdn$2.7 billion was widely dispersed; there were seven deals during the month for over Cdn$100 million in value. For context, the last time this number was reached during a calendar month was in September 2014, which was a time before OPEC stopped supporting the oil price and oil was trading for over US$90 per barrel.

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Source: CanOils Oil & Gas M&A Review June 2016

Top 5 Deals Announced in June 2016 in Canadian E&P Sector

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Source: CanOils Oil & Gas M&A Review June 2016 (Includes deals in Canada only)

Penn West Petroleum Ltd.'s (TSX:PWT) sale in Saskatchewan was the biggest deal to be agreed for Canadian assets in the first six months of 2016 and was a continuation of the trend of private equity backed companies making large acquisitions in recent times. Teine Energy Ltd, the acquirer in the deal, is funding the deal through its own credit facilities and also through significant backing from the Canada Pension Plan Investment Board. 

Encana's (TSX:ECA) deal to sell some northwestern Alberta assets follows two major asset sales by the company in the U.S. as the company looks to streamline its portfolio, while Athabasca Oil Corp. (TSX:ATH) fresh off closing its merger in the Duvernay and Montney shale plays with Murphy Oil Corp. (NYSE:MUR) last month, has become the latest of many Canadian E&P companies to make a royalty sale.

Full analysis of all the deals listed here and every other deal story involving a Canadian E&P company in June 2016 is available in the report, along with a detailed look at every asset put up for sale in a public listing. 

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Nigeria’s Oil Export Woes, Attacks on Majors and Why Merger Deals have Virtually Halted

Posted by Paul Harris

Jul 12, 2016 6:54:25 AM

Oil production has fallen dramatically and acquisition deals have ground to a virtual halt so far in 2016 in Nigeria, as the country continues to grapple with militant attacks on energy installations.

The concerns over export levels centre on oil installations in the Niger Delta that have been repeatedly targeted in recent months, creating significant unrest and threatening oil export volumes.

It hardly needs stating that energy production and exports are absolutely pivotal to the health of the economy of Nigeria, where several major international operators have significant stakes. Glacier Media’s Evaluate Energy data indicates that ExxonMobil produced 297,000 barrels a day (b/d), Royal Dutch Shell 275,000 b/d, Chevron 271,000 b/d, Total 228,000 b/d, and ENI SpA 132,000 b/d during 2015.

Crude oil production within the troubled West African state has plummeted during the first half of 2016. In May alone, output had fallen by 461,000 b/d when compared to fourth quarter averages in 2015, to 1.42 million b/d. May production was down 251,000 b/d compared to April as the slide continued, according to OPEC’s report on crude oil production from secondary sources.

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Source: OPEC Monthly Oil Market Report – June 2016 (Secondary sources)

Among Africa’s OPEC-member nations, the same OPEC data indicates Nigeria lagged behind Angola in terms of year-to-date crude oil production to May. Our Evaluate Energy data indicates that oil exports from Nigeria topped out in 2010 at 2.25 million b/d. With the exception of a small increase in 2014, exports have fallen every year since 2010, and stood at just over 2 million barrels in 2015.

As market uncertainty prevails in Nigeria, merger and acquisition activity has fallen dramatically. According to our 2016 data, so far this year just two deals have been announced. That compares to 13 deals announced in each of the two years prior.

The larger of the two deals in 2016 involved Canadian-listed Mart Resources Inc. (TSX: MMT), which agreed a Cdn$367 million deal (including debt) to be acquired by Midwestern Oil & Gas Company Ltd. and San Leon Energy Plc.

Midwestern had originally considered purchasing Mart in March 2015 – a deal that would have been worth around Cdn$524 million (including debt) at the time. Later that year, Mart was courted by Delta Oil Nigeria BV in a Cdn$394 million deal. That deal, however, was terminated due to deteriorating oil prices. Our Canoils Canadian asset team covered in-depth Mart’s various agreements to sell the company in our usual monthly M&A reviews: http://info.evaluateenergy.com/evaluate-energy-canoils-oil-gas-reports-studies-for-download

The second Nigerian M&A deal so far this year saw MX Oil plc acquired by GEC Petroleum Development Co. Ltd. for US$18 million.

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While M&A deal-flow has dried up, the activities of a militant group, known as the Niger Delta Avengers (NDA), have continued. The NDA’s demands are varied and are reported to include the ownership structure of oil blocks:  http://www.ibtimes.co.uk/who-are-niger-delta-avengers-nigerias-oil-gas-production-threatened-by-new-militants-1559022

Unrest naturally breeds uncertainty. Production continues, but disruption to operations has been painful: http://www.nytimes.com/aponline/2016/07/07/world/africa/ap-af-nigeria-oil-crisis.html?_r=0

In the past week, the militants struck again. According to reports, the NDA blew up three manifolds operated by Chevron Corp. The NDA claims to have also blown up a well and pipelines in the country’s southern oil hub: http://www.reuters.com/article/us-nigeria-delta-chevron-idUSKCN0ZM2O9

While efforts are made to tackle the disruption, markets will watch on in hope of a resolution. As a side note, a Nigerian, Dr. Mohammed Sanusi Barkindo, takes the helm as secretary general of OPEC next month: http://www.opec.org/opec_web/en/press_room/3529.htm. Dr. Barkindo is formerly a managing director of state enterprise the Nigerian National Petroleum Corp.

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Global Upstream Oil & Gas M&A Reaches $25.6 Billion in Q2 2016

Posted by Eoin Coyne

Jul 6, 2016 10:15:10 AM

Total global spend on upstream M&A deals rose an encouraging 38% in the second quarter, driven by improved oil prices and market confidence, according to Evaluate Energy's review of global upstream oil and gas M&A activity in Q2 2016, which can be downloaded now. 

Oil exceeded $50 a barrel during Q2 – the first time it has done so since July 2015. This is clearly a principal driver of M&A activity; should prices continue to rise, we would anticipate deals to follow.

Q2 upstream deals were worth a combined $25.6 billion, according to our latest data, compared to $18.5 billion in Q1. Yes, banks remain wary of over-committing on oil assets, but several companies are acting now rather than waiting for further rises in prices and asset values.

Download the full report here for details on all the major deals, the motivation behind them, exclusive analysis and a brief outlook for the rest of 2016.

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Source: Evaluate Energy Q2 2016 Upstream M&A Review

Top 10 upstream deals in Q2 2016

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Source: Evaluate Energy Q2 2016 Upstream M&A Review

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