“It is clear that the upcoming investments will not happen, I do not know which of the major international companies will risk it,” he predicted in an interview with Agence France-Presse.
Washington, ignoring the Europeans’ warnings that it would re-impose the sanctions imposed under the multilateral agreement in 2015, has been back on Iran in return for a pledge to freeze its nuclear program.

US Secretary of State Mike Pompeo warned that European companies, which would continue to deal with Iran in sectors banned under US sanctions, would “be held responsible.”

The United States launched a strategy to search for markets to sell its natural gas and exported 17.2 billion cubic meters in 2017 to EU ports.

According to EHSMarket, the total capacity to import natural gas in Europe will increase by 20% by 2020.

Millions of consumers and industries could stand to win after the world’s biggest natural gas exporter agreed to match prices in central and eastern Europe with markets in the west. As part of an accord to settle a seven-year-old antitrust case with European regulators, Gazprom agreed to remove restrictions on pipeline flows, and give customers the right to resell, swap and check their rates against markets in the Netherlands and Germany.
The agreement brings customers in the east more in line with the conditions western utilities from RWE to Eni have sought from Gazprom through negotiations or via the courts.
“I expect to see lower gas prices in southeast Europe as Gazprom brings them closer to those paid by the buyers in western Europe,” said Elchin Mammadov, a utilities analyst at Bloomberg Intelligence in London.
The settlement will speed up the transformation of how Gazprom runs its business in Europe, said Simone Tagliapietra, analyst at the Bruegel think-tank in Brussels. “Gazprom is aware that the European gas market is changing,” she said. “They are simply adapting to the new market conditions.”
The agreement is more effective than immediately slapping Russia’s state-run export monopoly with a fine because it includes binding pledges to enable the free flow of gas at competitive prices in Central and Eastern Europe, the European Commission said on Thursday.
“These obligations will significantly change the way Gazprom operates in central and eastern Europe to the benefit of millions of European consumers when they heat their houses, when they cook their food and to the benefit of European businesses who rely on gas for their production,” EU Competition Commissioner Margrethe Vestager told reporters in Brussels on Thursday.
Because of Gazprom’s “monopolistic” position in eastern Europe, it’s those nations that will benefit the most from the agreement and help cut prices, said Geoffroy Hureau, the secretary-general of Cedigaz, a Paris-based industry research group. Meanwhile, the company’s biggest client in Europe is just happy that the case is coming to an end.
“These things dragged on for too long – they are a burden to discussions on other topics,” Uniper’s chief executive officer Klaus Schaefer said in an interview in St Petersburg. “Therefore to get clarity on this in due course is important.”
Uniper was spun off from EON SE two years ago. EON was among the first utilities to seek more flexible terms from Gazprom back in 2009. The financial crisis had damped demand for the fuel and made market rates, which utilities use to sell the fuel to their own clients, cheaper than fuel from Gazprom.
The settlement comes as Russia faces UK accusations it poisoned a double agent that sparked the largest collective expulsion of Russian intelligence officers. Still, a thaw in relations with Europe – an opportunity for rapprochement – came this month when the US pulled out of the Iran nuclear deal, angering other world powers. The EU’s antitrust case has been a thorn in Gazprom’s side since regulators conducted raids in 2011. But geopolitics crept into the antitrust case from the start after Russian President Vladimir Putin signed a decree in 2012 that gave the government the right to protect Gazprom from EU inquiries, but the commission stuck with its case.
Customers that bought gas originally for delivery to Hungary, Poland or Slovakia, can choose to have Gazprom deliver all or part of it to Bulgaria or the Baltic States instead and vice versa against a fee, the EU said.
But despite the outlook for better deals in the region, Poland’s Deputy Foreign Minister Konrad Szymanski told state newswire PAP he was disappointed that there were no penalties or compensation for years of higher prices than their western competitors. Lithuania doesn’t rule out appealing the decision of the European Commission not to fine Gazprom, Interfax reported, citing Prime Minister Saulius Skvernelis. “I know that some would have liked to see us fine Gazprom instead, no matter the solution on the table,” Vestager told reporters. “But a fine would not have achieved all of our competition objectives.” The Commissioner also underlined that if Gazprom breaks any of these obligations, it can impose a fine of as much as 10% of the company’s worldwide sales, without having to prove an infringement of EU antitrust rules. The EU obligations will be in place for eight years. “It is the enforcement of the Gazprom obligations that begins today,” Vestager said.
Deputy chief executive officer Alexander Medvedev said that Gazprom is “satisfied” with the settlement.
“We were always committed to cooperate in good faith in order to find a constructive, mutually acceptable solution in accordance with the established procedure,” he said in a statement.
“We believe that today’s decision is the most reasonable outcome for the well-functioning of the entire European gas market.”

•  Hedge funds cut Brent wagers by most since June 2017
•  Saudi Arabia signals OPEC and allies may boost production

Money managers’ reluctance to get behind the oil rally is finally paying off.

Hedge funds trimmed their net-long position — the difference between bets on a price increase and wagers on a drop — in Brent crude by the most in almost a year. The cuts came as the global benchmark capped its first weekly drop since early April, sliding below $80 a barrel after Saudi Arabia and Russia said OPEC and its allies may boost oil output in the second half of the year.

“Traders thought that the market was in the process of topping out,” John Kilduff, a partner at Again Capital LLC, a New York-based hedge fund, said by telephone Friday. Oil prices had a “swift reaction today to the musings by OPEC to potentially add more supply to the market. We will be very headline-driven over the next few weeks.”

Oil retreated from the highest prices in almost four years as Russian and Saudi energy ministers signaled that the coalition led by the Organization of Petroleum Exporting Countries may gradually raise oil production to assuage consumer anxiety about higher prices. Their comments mark a major shift in strategy for the historic alliance forged in 2016 to erase a global crude glut.

“I think in the near future there will be time to release supply” smoothly to avoid shocking the market, Saudi Energy Minister Khalid Al-Falih said at the St. Petersburg International Economic Forum in Russia. When OPEC, Russia and other major producers meet in June “we will do what is necessary” to reassure buyers, the minister said.

He spoke after talks with his Russian counterpart Alexander Novak, who said the output boost would start in the third quarter, if it’s approved by other members of the group. Both men said the size of the increase was still subject to negotiation.

Hedge funds lowered their Brent net-long position by 8.6 percent in the week ended May 22 to 501,634 contracts, according to ICE Futures Europe data on futures and options released Friday. That was the biggest decline since June 2017.

Money managers’ net-long position in West Texas Intermediate crude fell by 2 percent to 377,520 futures and options, the lowest since November, according to U.S. Commodity Futures Trading Commission released Friday. Longs slipped less than 0.1 percent, while shorts climbed 23 percent, the biggest jump since April.

“You want to get out of the long positions if you are expecting that OPEC is going to increase production,” James Williams, president of London, Arkansas-based energy researcher WTRG Economics, said by phone. “It makes perfect sense for the folks that are long to say, ‘How much longer can this thing continue to grow?’”

Disruption Threat

Crude had rallied earlier this month on the dual threat of supply disruptions from Iran and Venezuela, which together account for about 14 percent of OPEC’s production. Still, the coalition is weighing the possibility of easing output limits at a time when drillers are pumping record amounts of crude from American shale basins.

“The market kind of overextended itself, ” Gene McGillian, manager of market research for Tradition Energy in Stamford, Connecticut, said by phone. “With the Saudis now saying they’re limiting their production cuts and geopolitical risk already priced in, there is going to be some uncertainty.”

A dearth of pipelines in West Texas’ Permian Basin, the most prolific U.S. oil play, is leaving supplies trapped in the region. That’s expanding the nation’s surplus of the fuel as American production tops 10 million barrels a day.

U.S. inventories climbed by 5.78 million barrels to about 438 million barrels in the week ended May 18, data from the Energy Information Administration showed. That was a surprise increase compared with the 2 million-barrel decline predicted in a Bloomberg survey.

But analysts and traders predict that stockpiles may decline in the coming weeks, bolstering prices. Data provider Genscape Inc. was said to report that inventories fell by about 475,000 barrels between May 18 and May 22 at the key pipeline hub in Cushing, Oklahoma.

Oil prices have “been extremely extended for a long period of time,” Kyle Cooper, a consultant at brokerage Ion Energy Group LLC, said by phone Friday. The “EIA report was bearish with a nearly 6 million-barrel build in total petroleum. The more important thing is how that was followed up today with OPEC and Russia regarding the possibility of removing some of those supply constraints.”

•  Easing output curbs “on the table”; no decision yet: Al-Falih
•  OPEC, allies to discuss loosening supply caps in June: Novak

Saudi Arabia and Russia, the oil producers who led the effort to shrink a global glut, said they are discussing easing output curbs for the first time.30

While scaling back the supply caps is “on the table,” no decision has been made, Saudi Arabian Energy Minister Khalid Al-Falih said in an interview early Friday morning in St. Petersburg. The Organization of Petroleum Exporting Countries and its partners will in June discuss loosening the curbs that began in 2017, Russian counterpart Alexander Novak said at the same interview after a meeting between the two officials.

Speculation is swirling over when and by how much the producers will scale back cuts after they eliminated an inventory surplus that had sparked a price crash about four years ago. Market uncertainty has risen following renewed U.S. sanctions on Iran that may curb the Islamic Republic’s exports, and as economic turmoil in Venezuela drives a collapse of the OPEC member’s oil industry. Crude’s rebound is also spurring concern that demand may falter.

Russia and Saudi Arabia share a common view on “consuming countries’ anxiety and concerns over potential supply shortages,” Al-Falih said. “We will ensure that the market remains in its trajectory towards rebalancing, but at the same time we will not overcorrect.” The two nations will meet at least two more times before OPEC and its partners gather in Vienna next month, he said.

While Saudi Arabia has shown a desire for higher prices to bankroll domestic economic reforms and underpin the valuation of its state oil company in a planned initial public offering, the top OPEC member and its allies are facing pressure from consuming nations as well as crude producing companies.

High Enough
Indian Petroleum Minister Dharmendra Pradhan said earlier this month that he expressed concern about rising crude and its impact on consumers to Al-Falih. He added that the Saudi energy minister had assured him that the Middle East nation and other producers would ensure that adequate supplies are available and that prices remain reasonable. In developing countries from Brazil to the Philippines, drivers are complaining about high fuel costs.

In Russia, some of the largest oil producers called for more flexibility after almost 17 months of output curbs. The cuts have achieved their goal and crude prices near $80 a barrel are high enough, according to the bosses of Lukoil PJSC and Gazprom Neft PJSC. Novak said that he will hold talks with the nation’s crude producers next week or the week after to discuss the deal with OPEC.

“Earlier we said that we will monitor the market situation, now we can say that we are looking into the issue” of a smooth recovery in output to meet growing demand, Novak said in the interview on Friday. He added that he and Al-Falih discussed prices and the market situation, including Venezuelan production and risks related to Iran.

The Saudi minister said he’ll meet Novak again in Moscow on June 14, adding that another meeting between the two is possible before that.

U.S. Supply
In Washington, Democrats are using high gasoline prices, approaching $3 a gallon for the first time since 2014, as a political tool, accusing the White House of not doing enough to shield consumers.

Recent price gains have been driven by American actions such as President Donald Trump’s withdrawal from a 2015 deal between Iran and world powers that had eased sanctions on the Persian Gulf state in exchange for curbs on its nuclear program. Earlier this month, Al-Falih and United Arab Emirates Energy Minister Suhail Al Mazrouei said recent moves in oil prices have been driven by geopolitics and that global supply remains ample.

Additionally, record production in the U.S., which is not part of the deal among global producers to cut output, is a key issue that’s complicating strategy for OPEC and its allies.

Brent crude, the benchmark for more than half the world’s oil, was down 0.4 percent at $78.49 a barrel at 7:31 a.m. in London. Earlier this month, prices had traded above $80 a barrel for the first time since November 2014. U.S. West Texas Intermediate futures were at $70.49 a barrel in New York.

“We will be coordinating closely, monitoring the market almost on a daily basis,” Al-Falih said on Friday. “We’ll consult with other countries. Each of them has a voice and their voices matter to us.”

•  Riyadh supports a gradual increase in oil output over summer
•  Middle East oil producers worried about U.S. anti-trust laws

The world’s largest oil exporter just made quite a policy swerve. Within six weeks, Saudi Arabia has gone from advocating higher prices to trying to stop the rally at $80 a barrel.

The U-turn scrambled the outlook for oil markets, hit the share prices of oil majors and shale producers and set up a diplomatic wrangle with other members of the Organization of Petroleum Exporting Countries.

What changed? The supply threats posed by the re-imposition of U.S. sanctions on Iran oil exports earlier this month and the quickening collapse of Venezuela’s energy industry are both part of the answer, but they’re secondary to Donald Trump. On April 20, the president took to Twitter to lambaste the cartel’s push for higher prices. “Looks like OPEC is at it again,” he tweeted. “Oil prices are artificially Very High!”

Trump’s intervention gave typically strident voice to a concern held more widely in the U.S. and other consuming countries: oil’s rally from less than $30 in early 2016 to more than $80 this month risked becoming a threat to global economic growth.

On Friday, Saudi Oil Minister Khalid Al-Falih responded, saying his country shared the “anxiety” of his customers. He then announced a shift in policy that all but gave a green light for a market sell-off, saying OPEC and its allies were “likely” to boost output in the second half of the year.

“The tweet moved the Saudis,” said Bob McNally, founder of consultant Rapidan Energy Group LLC in Washington and a former White House oil official. “The message was delivered loud and clear to Saudi Arabia.”

After Al-Falih’s comments, made following a meeting with his Russian counterpart in St. Petersburg, saw crude drop more than $3 to below $67 a barrel in New York on Friday. The bullish tone of recent market chatter, increasingly punctuated with talk about oil prices climbing past $100, $150 and even $300, suddenly looks overdone.

Looks like OPEC is at it again. With record amounts of Oil all over the place, including the fully loaded ships at sea, Oil prices are artificially Very High! No good and will not be accepted!

(Bloomberg) — The geologist who earned the wrath of shale drillers a decade ago with forecasts that natural gas was about to run out is now warning that the Permian Basin has just seven years of proven oil reserves left.

Arthur Berman, a former Amoco scientist who now works as an industry consultant near Houston, said the Permian region of Texas and New Mexico that currently pumps more oil than any other North American field won’t last for long. And the Eagle Ford shale about 350 miles (560 kilometers) away in South Texas isn’t looking good either.

Berman’s grim outlook, based on analyses of reserves and production data from more than a dozen prominent shale drillers, flies in the face predictions from the U.S. Energy Department, Chevron Corp. and others that the Permian is becoming one of the dominant forces in global crude markets.

Permian output already exceeds that of three-fourths of OPEC members.

“The best years are behind us,” Berman told a gathering of engineers, geologists, lawyers and financiers at the Texas Energy Council’s annual gathering in Dallas on Thursday. “The growth is done.”

Berman came to prominence as a shale skeptic and peak-oil advocate during the first decade of the new century, when intensive fracking and sideways drilling techniques were just beginning to unlock vast reserves of gas from shale fields in Texas and Louisiana. At the time, his dire warnings that shale gas was mostly hype drew the ire of fracking pioneers including Devon Energy Corp. and Chesapeake Energy Corp.

In 2009, Devon’s exploration chief Dave Hager — who has since risen to CEO — published an op-ed piece in an Oklahoma City newspaper to refute Berman’s thesis. In it, Hager likened shale to a World Series-winning home run and said Berman “is in the stands speculating on whether the slugger is on steroids.”

Berman on Thursday said investors banking on shale fields to make major contributions to future global crude supplies will be disappointed: “The reserves are respectable but they ain’t great and ain’t going to save the world.”

Still, he hasn’t sold the stock of shale driller EOG Resources Inc. that he inherited from his deceased father “because they’re a pretty good company.”

His parting advice to the assembled was, “Conserve what you’ve got, learn to live with less, open your eyes and enjoy the rest of your day.” No one participated in the Q and A session.

The shale boom’s back in full swing, with fracking crews the busiest since 2014. The novelty this time around: Oil executives stressing their prudence, along with their production.
The combination of surging output, oil prices at three-year highs and spending under control means that the shale patch – which has notoriously burnt more cash than it makes as investors bankroll their expansion – got closer to a milestone in the first-quarter: Positive free cash flow. As oil rises above $70 a barrel, the outlook for the coming quarters looks even brighter.

It’s a shift that came with the help of new high-tech well systems, and at the insistence of investors pushing payback over growth. Here are five key takeaways from the first quarter to track moving forward: Production is thriving
EOG Resources Inc and Pioneer Natural Resources Co are among producers that posted record output, while keeping capital expenditures in check.
But how can they keep growing without overspending?

Producers have sought to cut costs since prices crashed more than three years ago, but those efforts can only go so far. It’s mainly better technology that’s allowing them to get more from each well without blowing their budgets.
Pioneer, in a recent presentation, offered insight into how its high-tech wells are delivering at a faster rate, a theme repeated over and over again in earnings calls. Devon Energy Corp said it completed the two highest-rate wells in the Delaware section of the Permian in its 100-year history, helping it to a 20% production boost.

Almost living within their means
Buybacks, dividend increases and a cap on capital expenditures. Oil executives couldn’t keep from crowing about their thriftiness while producing record amounts of product, and how their efforts can be a benefit to both their shareholders, and to continued growth.
The numbers back them up, showing a pretty good rise in free cash flow, starting from the end of 2016.

The oil rally’s flip side: HedgingA big risk facing some producers now is the amount of wrong-way bets on oil prices that they hold. When crude markets slumped, explorers used hedging contracts to lock in payments for future barrels that could now turn sour as futures trade above $70 a barrel.
Wood Mackenzie Ltd’s Andrew McConn estimates top producers will lose $7bn on their hedging contracts in 2018.

The reality on the ground
To make record production a reality, oil-service providers are sending a growing number of fracking crews to shale fields to blast the oil-rich layers of rock with water, sand and chemicals.
But for the service providers, that hasn’t translated into better profits yet.
The rush to respond to heightened demand has inflated costs for materials like sand and has triggered transportation bottlenecks and labour shortages. All that has weighed down on their first-quarter results. Schlumberger Ltd, the world’s biggest oilfield service provider, and Halliburton Ltd, the top fracker, have both promised investors things will improve. If that means increasing prices for their services, costs will rise for producers.

LONDON (Reuters) – A decade ago, the news that the world’s top oil and gas companies had less than 12 years of production left in their reserves might have caused a panicked sell-off in their shares.

But as consumers try to move away from fossil fuels to cleaner and cheaper energy sources, investors and executives say reserve size is no longer the gold standard for measuring the value and health of a company.

The cost of developing existing reserves and the amount of carbon those reserves produce has now become more important, they say. This is leading to a profound shift in company strategies.

“The quality of reserves and the commercial viability of reserves has eclipsed the quantity of reserves by far in recent years,” said Adi Karev, Global Leader for Oil and Gas at EY.

The sector is emerging from one of its longest and deepest downturns after an oil price slump that started in 2014.

The largest publicly-traded oil companies — Exxon Mobil, Royal Dutch Shell, Chevron, ConocoPhillips, France’s Total, BP, Equinor (formerly Statoil) and Italy’s Eni — have adapted. They saved money by cutting jobs and increasing technology spending and now make more money with oil at $60 a barrel than they did at $100.

But they also cut spending on exploration for new resources and development of new fields. This led to a decline in reserves.

An analysis by Reuters and Guinness Asset Management of the annual reports of those eight companies shows that the size of their oil and gas reserves, when added together, fell to 91 billion barrels in 2017. That was the lowest since the same amount in 2005.

BP and Chevron’s oil and gas reserves increased by a small 5 percent since 2014. Eni was the only one to significantly boost its reserves by over 20 percent thanks to the discovery of the giant Zohr gas field off the coast of Egypt.

The cumulative reserve life – the number of years a company can sustain its current production levels with existing reserves – of the eight companies fell to 11.7 years in 2017. That was the lowest level in at least 20 years although that drop is also the result of a sharp increase in production. Reuters does have access to data going back beyond 1998.

Exxon’s reserves life shrank from 17 years in 2014 to 15 in 2017. Eni’s from 10.6 to 10.1 years despite its discoveries. Shell slipped from 12 to 9 years over the period.

“There is clear deterioration (in reserves) and this will be a problem in time,” according to Jonathan Waghorn, manager of the energy fund at Guinness Asset Management.

But for now, “10-12 year’s reserve life should be fine, so it is not a materially important component between the Majors.”

“THE BEST BARRELS”

With electric vehicles on the ascent and a peak for fuel demand on the horizon, the focus on the reserves is shifting to the quality of the reserves rather than the quantity

“At some point we see a shrinking oil and gas industry, when that will be I do not know, but then it is really important that the best barrels come in and that will be increasingly a competitive factor.”

Some companies are already changing strategies to adapt to the new focus.

Oil prices are not expected to rise sharply in the long-term and governments are seeking to reduce pollution and greenhouse gas emissions. This means firms are adjusting by setting ceilings for the cost of projects, often below $35 a barrel. Oil reached a $80 a barrel this month, the highest since late 2014.

Crude oil and natural gas have different grades and the cost of pumping them can vary hugely. Saudi Arabia’s oil is easier and therefore cheaper to extract than Angola’s complex deepwater wells.

Canada’s oil sands have become less attractive due to their high cost of extraction and high carbon intensity. Exxon wrote down a large part of its Canadian oil reserves in 2017. Its largest rival, Shell, has sold most of its Canadian assets in recent years.

North American shale which has emerged over the past decade can be developed relatively quickly and at low cost, in contrast to multi-billion dollar deepwater projects that take years to develop.

The Permian basin in Texas, the heartland of the shale oil boom in recent years, saw production costs drop sharply to as low as $30 a barrel.

Exxon and U.S. rival Chevron have both acquired large acreage in the Permian in recent years. Shell is also expanding in U.S. shale.

The Gulf of Mexico also has low extraction costs because it has large reservoirs of oil and some infrastructure is already located there such as services companies and onshore bases.

Brazil’s pre-salt reserves also have low costs as there are huge reservoirs and also some existing infrastructure. All eight companies are there and several have recently sharply increased their production in the basin.

“We are now getting to the point that the focus on efficiencies and producing reserves at a low level is what investors expect,” Karev said.

Higher oil prices offer “temporary” relief to the oil exporters of the Middle East and North Africa (Mena) whose economic prospects are improving, according to the Institute of International Finance (IIF), the Washington-based economic think tank.

Oil prices rose rapidly in the past six months on unanticipated sharp output fall in Venezuela, the extension of the producers’ pact on production cuts to the 2018- end, the escalation of tensions in the Mena, which enhanced risks of oil supply disruption; and higher global oil demand.  We have revised upward our average Brent oil price assumption to $72 per barrel for 2018 (33% increase form 2017),” IIF said.

With the projected $18 increase in average oil prices in 2018 against last year, it expects the cumulative current account surplus for the nine Mena oil exporters (Saudi Arabia, the UAE, Kuwait, Qatar, Oman, Bahrain, Algeria, Iraq and Iran) to increase from $56bn in 2017 to $233bn (9.5% of gross domestic product) in 2018. “The fiscal situation for Mena oil exporters (except Bahrain and Oman) is now on firmer footing. The respective authorities in the region have implemented serious fiscal adjustment in recent years,” it said. 

Higher oil prices, combined with additional non-hydrocarbon revenue, should more than offset the 7% average increase in public spending, leading to narrower deficits (excluding investment income), according to the IIF. “We expect the consolidated fiscal deficit for the nine Mena oil exporters to decrease from 7.5% of GDP in 2017 to 3% in 2018,” it said, adding when included investment incomes, which are very large in Kuwait, the UAE and Qatar, the cumulative deficit will be much smaller.

Highlighting that gross public foreign assets will resume its rise to $2.9trn by end-2018; it said about 70% of these assets are in the form of sovereign wealth funds. With relatively little public external debt, the region’s net public external assets position of $2.6bn (108% of GDP) is substantial, the report added. Expecting non hydrocarbon growth to accelerate from 2.3% in 2017 to 2.8% in 2018 (still well below the average growth of 6.2% in 2001-2014); IIF said the growth pickup will be supported by the shift to fiscal expansion following three years of consolidation. A tighter monetary stance in the six GCC countries and Iraq, whose currencies are pegged to the US dollar, could offset some of the gains from expansionary fiscal stances. “We expect a cumulative increase of 100 bps in key policy rates, in line with the four Fed hikes of 25 bps each,” it said.