new base 821 special 03 april 2016

Copyright © 2015 NewBase www.hawkenergy.net Edited by Khaled Al Awadi – Energy Consultant All rights reserved. No part of this publication may be reproduced, redistributed,

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NewBase 03 April 2016 - Issue No. 821 Edited & Produced by: Khaled Al Awadi

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UAE: Masdar discusses with private sector ways to boost use of environment-friendly vehicles

(WAM) – Dr. Ahmed bin Thani Zeyoudi, Minister of Climate Change and Environment, has discussed with Al-Futtaim Auto Group, investment opportunities, joint co-operation and co-ordination to promote the use of environmentally-friendly vehicles in the state.

The move is part of the wise leadership’s vision to enhance co-operation and co-ordination between the public and private sectors in order to protect the environment, promote sustainability, reduce environment pollution and curb emission of the carbon footprint nationwide.

During the meeting, the two parties focussed on ways to reduce emissions from cars and promote the use of hybrid vehicles with lower emission rates as compared with conventional cars. They also discussed encouraging people to use hydrogen cars deemed to have the least impact on the environment, with their emissions at zero rate.

Dr. Al Zeyoudi stressed the importance of outsourcing government services to the private sector in line with the vision of the leadership. He pointed out that such co-operation is of paramount importance to maintain the role of the UAE's leading position in the region and the world as well.

He referred to the efforts of the ministry towards enhancing work with strategic partners and environmental sectors in the country to achieve the targets of the national agenda of the UAE Vision 2021, and unify the national efforts in the environmental fields so as to shift towards a green and sustainable economy.




UAE: Jebel Ali power plant leads Dubai on solar energy The National - LeAnne Graves

More than 5,000 solar panels are helping a Dubai power station to become one of the region’s largest, single rooftop arrays, but companies say the authorisation process is inhibiting a large-scale roll-out.

The Dubai Electricity and Water Authority (Dewa) announced yesterday that its Jebel Ali power plant was producing 1.5 megawatts of power, which is enough to power about a quarter of a million homes, according to the US-based Solar Energy Industry Association.

Dewa installed 5,240 photovoltaic panels on the roof of the water reservoir at M-Station, a power production and desalination plant with a total capacity of more than 2,000MW of electricity and 140 million imperial gallons of water a day.

The solar rooftops are part of Shams Dubai, a three-pronged initiative to help the emirate reach its goal of 25 per cent reliance on solar energy by 2030.

Many other companies trying to get on board with the rooftop initiative are facing delays because of the approval process.

Phanes Group, a Dubai-based solar energy developer, plans to add 20 to 30MW of solar power, which translates to about US$30 million in investment. “We have set that deliberately lower because, at the moment, Shams is still young and we have to see how quickly we get through the Dewa authorisation process," said Martin Haupts, the managing director of Phanes.

He said the installation of 1MW of solar on a rooftop would average about four to six weeks, but Dubai’s regulatory process has morphed that time span to three to six months, which is the main reason that is keeping volume low. “In terms of manpower and equity available, [Phanes] could obtain that for 30 to 50MW in 18 months. However, I’m sceptical that we would get that much through the authorisation process," he said.

Local firm Yellow Door Energy has more than 80MW of projects under development and just announced its latest deal with Berger Paints, to provide 400 kilowatts of solar power.

“We’re waiting for municipal approval [for projects], which is the bottleneck most companies are facing," said Jeremy Crane, the chief executive of Yellow Door. Dewa is actively working with the municipality to help create a more efficient system, according to a source working at the utility provider.




UAE: TAQA Slashes 2016 CAPEX Despite Narrower 4Q Loss by Reuters|+ NewBase

Abu Dhabi National Energy Co (TAQA) has slashed its proposed capital expenditure for 2016 despite reporting on Thursday a narrower fourth-quarter loss, as the company is impacted by lower oil prices.

Global oil firms have been scaling back investments and cutting costs to cope with a slump in the price of crude. TAQA, 75 percent owned by the government of Abu Dhabi, said it had reduced capex by 52 percent in 2015 and would cut spending by a further 42 percent in 2016 to no more than 1.8 billion dirhams ($490 million). The company has also been shedding jobs and has reduced its workforce by around a quarter since 2014, following the elimination of 32 percent of its oil and gas jobs and 55 percent of its headquarters staff. "We exceeded all of our internal targets while shifting to a leaner and more efficient organisation worldwide, with significant revisions to our operating model," Edward Lafehr, chief operating officer, said in the statement. The state-controlled oil explorer and power supplier made a loss of 1.22 billion dirhams in the three months to Dec. 31, versus a net loss of 3.63 billion in the same period of 2014. It posted a net loss of 1.8 billion dirhams for 2015 as a whole compared with a loss of 3.01 billion in 2014. The annual loss came on the back of lower revenue from oil and gas, which nearly halved in 2015 to 6.29 billion dirhams from 12.0 billion as commodity prices slumped. TAQA also booked a post-tax impairment charge of 681 million dirhams in 2015. TAQA will not pay dividends for 2015, according to a bourse filing, the third successive year in which the company has not paid anything to shareholders according to Thomson Reuters data. In line with the company's strategy of selling non-core assets, TAQA plans to divest its stakes in Abu Dhabi-based Massar Solutions and the Lakefield wind power project in the United States, the statement added. TAQA has already said Lakefield would be sold to Qatar's Nebras Power, while sources told Reuters in September that shareholders of Massar Solutions had picked HSBC to advise on the sale of 40 percent of the car rental firm. ($1 = 3.6726 UAE dirham)




Indonesia: JGC Clinches $240M EPC Contract to Build Gas Processing Plant in Aceh… JGC Corp.|Press Release

Japan's JGC Corporation reported Friday that its unit JGC Indonesia, jointly with PT. Encona Inti Industri, has been awarded an engineering, procurement and construction (EPC) contract for the construction of a gas processing plant in Aceh Province, Sumatra, Indonesia by PT Medco Energi Internasional Tbk's subsidiary PT Medco E&P Malaka.

The lump-sum turnkey contract has a value of approximately $240.3 million (JPY 27 billion) and is scheduled for completion in the first quarter of 2018 (1Q 2018). The project contract calls for the construction of a plant with a processing capacity of 90 million standard cubic feet per day (MMscf/d) to produce sales gas, condensate, and solid sulfur from natural gas produced in Block A that is being developed by Medco and its partners in Aceh -- an area rich in natural resources such as oil and gas. The produced sales gas will be used principally by a gas-fired power plant belonging to Indonesia’s state-owned electric power company in Aceh and by a state-owned fertilizer company. In the 1970s, JGC was the first company to set up an EPC-capable subsidiary in Indonesia when it established the former PT. Pertafenikki Engineering (renamed JGC Indonesia in 2007). Through to the present, the subsidiary has been steadily accumulating project experience while responding to local needs. This is the largest project in the history of JGC Indonesia, and JGC understands that the contract has been awarded to JGC Indonesia on the basis of its experience in Indonesia and the high evaluation accorded to its project execution capabilities, in addtion to its cost-competitive proposal. JGC is now promoting the strengthening and expansion of its overseas EPC subsidiaries, and intends to further enhance JGC Indonesia’s project execution capabilities through the successful execution of this very important project. MedcoEnergi indicated separately that first gas from the Block A gas project will commence in 1Q 2018 under a gas sales agreement signed in January 2015 with Indonesia's national oil company PT Pertamina to deliver 58 billion British Thermal Units (Btu) per day, or 198 Trillion Btu over 13 years. “This is just the first phase of our plans to develop and monetize the resources on this Block,” Roberto Lorato, CEO of MedcoEnergi, said in a company's statement.




Russia oil output highest in 30 years ahead of Doha meeting Reuters + NewBase

Russia’s oil production rose 0.3% to 10.91mn bpd in March, its highest level in nearly 30 years, raising questions over Moscow’s commitment to freeze output ahead of a producers’ meeting in Doha later in April. Energy Ministry data yesterday showed that in tonnes, oil output reached 46.149mn in March versus 43.064mn, or 10.88mn bpd, in February. Leading oil producers, including Russia, are due to meet in Doha on April 17 for talks on how to freeze oil output at the average levels reached in January to support the global market.

But the increase in Russian output to levels not seen since 1987, when it reached a record high of 11.47mn bpd, suggests it may prove difficult for Moscow to stick to oil output freeze commitments. Some oil industry observers said that it would be hard for Russia to stick to an output freeze since the domestic industry is dominated by several big oil companies such as Rosneft, Gazprom and Lukoil; each with its own agenda. The Energy Ministry declined immediate comment on the data. The latest production statistics showed that companies, categorised by the ministry as “small producers” were behind the higher production total, with an increase of 1.5% to 4.92mn tonnes (1.16mn bpd) in March. An 11.9% rise in output from joint ventures with foreign oil companies also contributed to the increase in the total production figure. Oil output under production sharing agreements, designed in the 1990s to encourage investment by foreign oil companies, jumped to 1.51mn tonnes (357,000 bpd) last month. Output from major Russian oil companies fell last month, lead by a 0.7% output decline at world’s biggest listed oil producer Rosneft. Output at Lukoil and Surgutneftegaz edged down by 0.1. Rosneft has said it plans to keep production unchanged this year after it fell by 1% in 2015. Natural gas production was at 53.98bn cubic metres (bcm) last month, or 1.74 bcm a day, versus 52.92 bcm in February.




US Ethane production expected to increase as petrochemical consumption and exports expand Source: U.S. EIA, Short-Term Energy Outlook, March 2016

Ethane production is expected to increase from 1.1 million barrels per day (b/d) in 2015 to 1.4 million b/d in 2017, accounting for two-thirds of total U.S. hydrocarbon gas liquid (HGL) production growth. Ethane, a key feedstock for petrochemical manufacturing, is recovered from raw natural gas at natural gas processing plants.

Over the past five or six years, the amount of ethane contained in domestically produced raw natural gas has exceeded the capacity to consume and export it. This oversupply kept ethane prices relatively low, hovering at or below the price of natural gas, leading producers to reject the ethane stream by leaving it mixed with the stream that is marketed as pipeline natural gas, which is mostly methane. Beginning in 2012, the availability of relatively inexpensive ethane encouraged a wave of investments in ethane-consuming petrochemical plants and export facilities. The recognition that these investments would provide an outlet for U.S. ethane also encouraged investment in facilities to recover ethane from raw natural gas and to transport it to market. Many of these projects, including de-ethanization facilities, ethane pipelines, petrochemical plants, and ethane export facilities, have either recently been completed or are currently under construction and will come online in the next few years. These projects increase take-away capacity for ethane, especially in the Marcellus and Utica shale regions, mainly in Pennsylvania, Ohio, and West Virginia, where market outlets for rapidly growing natural gas supply were previously limited to pipeline natural gas.




As new ethane-consuming petrochemical and export capacity reduces the ethane oversupply in 2016 and 2017, ethane prices are expected to generally remain above natural gas prices, leading to a rise in ethane recovery to meet demand and export growth. EIA's recent report on the Short-Term Outlook for Hydrocarbon Gas Liquidsexamines ethane production, consumption, exports, and infrastructure projects. U.S. ethane consumption, which was 1.05 million b/d in 2015, is forecast to increase 50,000 b/d in 2016 as expansion projects at ethylene-producing petrochemical plants increase feedstock demand for ethane. In 2017, ethane consumption is projected to increase another 80,000 b/d as capacity begins to ramp up at five new petrochemical plants and at a previously deactivated plant.

Source: U.S. Energy Information Administration, Short-Term Outlook for Hydrocarbon Gas Liquids

In 2014, the United States switched from being a net importer of ethane to a net exporter after the opening of two new ethane pipelines that began transporting ethane from North Dakota and southwestern Pennsylvania to Canada. EIA's Short-Term Energy Outlook (STEO) expects annual average ethane net exports to increase from 60,000 b/d in 2015 to 230,000 b/d in 2017, as new export facilities and ethane-carrying ships enable ethane to reach overseas markets. On March 9, the United States shipped the first waterborne exports of ethane from the Marcus Hook, Pennsylvania terminal to Europe. A second ethane terminal is expected to open at Morgan's Point, Texas in the third quarter of 2016. The two terminals are expected to export ethane mainly to European and Asian countries.




NewBase 03 April 2016 Khaled Al Awadi

NewBase For discussion or further details on the news below you may contact us on +971504822502 , Dubai , UAE

US oil sheds 4 pct after Saudi comments on output freeze Reuters + NewBase

U.S. oil tumbled 4 percent on Friday after the Saudi deputy crown prince reportedly said the kingdom will not freeze production unless Iran and other major producers do so.

Futures slightly pared losses after oilfield services firm Baker Hughes reported its weekly count of oil rigs operating in the United States fell by 10 to a total of 362. At this time last year, drillers had 802 rigs in U.S. oil fields.

The dollar's first rebound in a week after stronger-than-expected U.S. jobs data added pressure on oil, making crude prices denominated in the greenback less attractive for holders of the euro and other currencies.

U.S. employment increased solidly in March and wages rebounded, signs of economic strength that could allow a cautious Federal Reserve to raise interest rates gradually.

"I think (the payrolls report) is probably what's sent us over the edge in oil," CMC markets analyst Jasper Lawler said.

Brent crude for June delivery fell $1.63, or 4 percent, to $38.70 a barrel. Brent rose 6 percent in the first quarter of this year, its first such increase since a 15 percent rally in the second quarter of 2015.

Oil price special

coverage




U.S. crude settled at $36.79 a barrel, down $1.55, or 4 percent after settling up 2 cents on Thursday. Prices rose almost 4 percent over January-March, also the first quarterly gain since surging nearly 25 percent in the second quarter of last year.

Oil had rallied for the past six weeks after major producers within and outside the Organization of the Petroleum Exporting Countries floated the idea of freezing output at January's highs.

But Saudi Deputy Crown Prince Mohammed bin Salman said the OPEC kingpin will not join the program without the participation of Iran and other major producers, Bloomberg reported.

The Saudi deputy crown prince also told Bloomberg Saudi Arabia is looking to create the world's largest public company as it plans to offload a stake of less than 5 percent of the Saudi Arabian Oil Company. The move would provide the kingdom with a cash infusion that would theoretically allow Riyadh to extend the high-production policy it spearheaded as OPEC's top exporter.

Prices have recently pulled back on low trading volumes and concerns about oversupply ahead of an oil producers' meeting in Doha to agree a possible output freeze on April 17.

Iran has steadfastly maintained that it will not contribute to any output freeze until its crude exports return to pre-sanction levels.

"The primary reason that oil prices are being dealt a solid dose of the WBWs (whoop-bang-wallops) today lies with Saudi Prince Mohammed bin Salman," Matt Smith, director of commodities research at Clipperdata, wrote in a commentary. "The King's son threw cold water on hopes of a production freeze."

A Reuters monthly survey showed this week that OPEC output rose in March on higher supply from Iran after the lifting of sanctions and near-record exports from southern Iraq.

Oil prices fell despite China's official Purchasing Managers' Index (PMI) showing an unexpected expansion in March, the first in nine months.

Earlier in the session, a drop in U.S. crude output put a floor under losses. Production fell for a fourth straight month in January to the lowest since October 2014.




Baker Hughes: US Drillers Cut Oil And Gas Rigs For 15th Straight Week Reuters + NewBase + BH The number of rigs drilling for oil and natural gas in the United States fell for the 15th straight week to the lowest level since at least 1940, data showed on Friday, as the energy price rout takes its toll on shale producers' financing and their ability to drill new wells. Drillers cut 14 oil and gas rigs in the week to April 1, bringing the total rig count down to 450, oil services company Baker Hughes Inc said in its closely followed report.

That compares with 1,028 oil and gas rigs operating in the same week a year ago. In 2015, drillers cut on average 22 oil and gas rigs per week for a total of 1,142 for the year, the biggest annual decline since at least 1988. Oil rigs alone fell 10 to 362, the lowest level since November 2009, while gas rigs declined by four to 88, the least since at least 1987, according to the data going back that far. Energy firms have sharply reduced oil and gas drilling since the selloff in crude markets began in mid-2014, forcing more than 50 U.S. producers to file for bankruptcy protection since the start of 2015. But a Reuters analysis found that bankruptcies so far are having little effect on U.S. oil production as distressed drillers tend to keep their wells gushing as they have figured out how to get more out of each well. What bankrupt and financially stretched producers are unable to do is drill new wells and since output from shale wells can fall as much as 70 percent during their first year, a sustained lull in drilling would gradually erode U.S. production. U.S. crude production is expected to decrease about 7 percent from 9.4 million barrels per day in 2015, the highest level since 1972, to 8.7 million bpd in 2016 and 8.2 million bpd in 2017, according to the latest federal estimates.




Many analysts think the combined oil and gas rig count will rise later this year with signs prices may have bottomed since U.S. crude futures hit a near 13-year low of $26.05 a barrel in February and U.S. gas futures fell to a near 18-year low of $1.611 per million British thermal units in March. Since hitting those lows, oil has soared over 40 percent to around $37 a barrel, while gas gained almost 25 percent to almost $2 per mmBtu. U.S. crude futures were fetching around $40 a barrel for the balance of 2016 and about $44 for calendar 2017. Day-to-day well operating costs in most U.S. shale fields remain well below $40 a barrel.

Stacked rigs are seen along with other idled oil drilling equipment at a depot in Dickinson




NewBase Special Coverage

News Agencies News Release 03 April 2016

As US Shale Drillers Suffer, Even The Bankrupt Keep Pumping Oil Reuters + NewBase

As oil prices nosedived by two-thirds since 2014, a belief took hold in global energy markets that

for prices to recover, many U.S. shale producers would first have to falter to allow markets to

rebalance.

But a Reuters analysis has found that bankruptcies are so far having little effect on U.S. oil production, and a tendency among distressed drillers to keep their oil wells gushing belies the notion that deepening financial distress will prompt a sudden output decline or oil price rebound. Texas-based Magnum Hunter Resources, the second-largest producer among publicly-traded companies that have filed for bankruptcy, is a case in point. It filed for creditor protection last December, but even as the debt-laden driller scrambled to avoid that outcome, its oil and gas production rose by nearly a third between mid-2014 and late 2015, filings show.

With U.S. oil prices now trading below $40 a barrel, the corporate casualties are already mounting. More than 50 North American oil and gas producers have entered bankruptcy since early 2015, according to a Reuters review of regulatory filings and other data. While those firms account for only about 1 percent of U.S. output, based on the analysis, that count is expected to rise. Consultant Deloitte says a third of shale producers face bankruptcy risks this year.




Once in Chapter 11, its CEO Gary Evans said the bankruptcy, which injected new funds to ensure it would stay operational, could help to "position Magnum Hunter as a market leader." The company did not respond to a request for comment for this story. However, John Castellano, a restructuring specialist at Alix Partners, said that all of the nearly 3,000 wells in which Magnum Hunter owns stakes have continued operations during its bankruptcy. Production figures can be hard to track post-bankruptcy, but restructuring specialists say that many bankrupt drillers keep pumping oil at full tilt. Their creditors see that as the best way to recover some of what they are owed. And as many bankrupt firms seek to sell assets, operating wells are valued more than idled ones. "Oil companies in bankruptcy do not seem to automatically curtail production," said restructuring expert Jason Cohen, a partner at the Bracewell firm in Houston. "Lenders are willing to let them continue to produce as long as economically viable." For most companies in bankruptcy or considering it, maximizing near-term production does make economic sense. Day-to-day well operating costs in most U.S. shale fields remain well below $40 a barrel. Bankrupt firms are also eligible for new financing that can allow them to keep pumping for some time. 50 And Counting

At least 20 publicly traded companies have filed for creditor protection since the start of 2015. They held at least 95,000 barrel of oil equivalent per day (boepd) in production, according to their




last disclosed annual output figures. Another 30 or so privately held companies also have gone bust, in what already is the biggest wave of North American bankruptcies since the subprime mortgage crisis.They account for just over 1 percent of U.S. output, but the figure is set to grow with banks expected to slash credit lines to energy firms in their biannual review of borrowing limits in April. In what could become the most high-profile reorganization in the sector, Oklahoma City-based SandRidge Energy Inc confirmed on Wednesday that it has hired advisers to review its options, including a bankruptcy filing. About a million barrels of U.S. oil production, over a tenth of the total, is under the control of firms considered "financially challenged" estimates Rob Thummel, a portfolio manager at Tortoise Capital Advisors Llc. Yet even if many more firms go bust, production is not expected to fall much. "I could see (bankruptcies) as a marginal contributor to lower supply, but if you ask me could it ever move the needle, the answer is no," said Bill Costello, a portfolio manager at Westwood Holdings Group. The reason is the remarkable gains in productivity of U.S. oil rigs in recent years. The Energy Information Administration (EIA) estimates that a well drilled late in 2015 produces twice as much as one from late 2013. As a result, the EIA forecasts output will only drop 7 percent this year to 8.7 million bpd, even after U.S. oil and gas producers have shed more than 100,000 jobs, slashed spending and idled 75 percent of rigs since the end of 2014. Many bankrupt firms can sustain their output thanks to so-called debtor-in-possession (DIP) financing for operating and other expenses made available by existing creditors, banks, or private equity firms. Magnum Hunter, for example, received $200 million in DIP funding, and so far is being run by the same management as before its bankruptcy. Many distressed producers have also drawn down their credit facilities or skipped bond payments prior to filing to conserve cash. Among the companies reviewed by Reuters, Swift Energy Co, Samson Resources Corp and American Eagle Energy Corp Co all chose to skip interest payments ahead of bankruptcy filings, citing ongoing talks with lenders to restructure their debt. With operating expenses for existing U.S. shale wells between $17 and $23 per barrel, most companies can keep pumping unless oil falls below $20 per barrel, says David Zusman, chief investment officer of Talara Capital Management. What bankrupt and financially stretched producers are unable to do is drill new wells and since output from shale wells can fall as much as 70 percent during their first year, a sustained lull in drilling would gradually erode U.S. production. Ultimately, the number of bankruptcies may matter less than the lack of funding. The lending reviews now underway are likely to leave more companies without sufficient credit to finance new drilling, analysts say. "We could see a 150,000-200,000 bpd fall in oil production if financially challenged producers were to slow spending," said Thummel.




China proposes $50tn global renewable energy network RT + NewBase

The company running China’s power grid is proposing a $50 trillion global electricity network to tackle pollution and climate change. If it goes ahead the network would use advanced renewable solar and wind technology and be operating by 2050.

Beijing’s network will be the world’s biggest infrastructure project, if given the green light. The State Grid has already signed a memorandum of understanding with the Russian energy grid Rosseti, Korea’s Electric Power and SoftBank Group of Japan.

According to State Grid’s Chairman Liu Zhenya, the planet is facing "three major challenges", which are energy scarcity, environmental pollution and climate change. Liu added that smart grids, ultra-high voltage (UHV) grids and clean energy are the only way to a green, low carbon, economical, efficient and open energy system with sustainable supply.

Liu also said the global network could boost the share of clean energy to 80 percent of global consumption, displacing fossil fuels as the main energy source.

"China is already the biggest country in the world for wind, solar power generation and also UHV grids. And has scale, so we can learn many things from China's success. Also, by interconnecting, we can help each other on supply and demand," SoftBank CEO Masayoshi Son told the Global Times. "It's a brilliant plan. It might encounter difficulties during construction but it's possible," Xue Jiancong, spokesperson for China Merchants New Energy Group, a leading renewable energy company, told NBC News. The major barriers for the project “are institutional, not technical,” former US energy official David Sandalow told the Wall Street Journal. “It’s an open question whether national governments will be open to such a revolutionary idea,” he added.




Obama and Xi announce joining climate change pact, urge others to do so

China and the US will sign the Paris Agreement on combating climate change next month, and urge other countries to do the same, presidents Barack Obama and Xi Jinping have announced. The two met on the margins of the nuclear summit in Washington.

“The United States and China will sign the Paris Agreement on April 22nd and take their respective domestic steps in order to join the Agreement as early as possible this year,” the two presidents said in astatement published by the White House on Thursday. “They encourage other Parties to the United Nations Framework Convention on Climate Change to do the same, with a view to bringing the Paris Agreement into force as early as possible.”

“Our two countries, with this joint statement, are making an important step forward in building on the success of Paris by urging and encouraging swift entry into force of that agreement,” said Brian Deese, Obama’s senior adviser, according to the Washington Post. Proposed in December at a conference in Paris,

the document aims to “strengthen the global response to the threat of

climate change in the context of sustainable development and efforts to eradicate poverty, including by holding the increase in the global average temperature to well below 2 degrees Celsius [3.6 degrees Fahrenheit] above preindustrial levels and to pursue efforts to limit the temperature increase to 1.5 degrees Celsius [2.7 degrees Fahrenheit].”

If signed and ratified by 55 countries – which represent 55 percent of global carbon emissions – the agreement will enter into force in 2020. The signing ceremony is scheduled for April 22, which is also Earth Day, at the United Nations in New York.

China is the world’s biggest emitter of carbon dioxide, due to its heavy coal use. However, China’s emissions went down by 4 percent in 2015, thanks to coal cutbacks driven in part by efforts to combat air pollution. As a result, the global CO2 emissions decreased by 1 percent. European and US emissions have flattened out as more people switched to natural gas, solar and wind energy.

Meanwhile in the US, President Obama’s Clean Power Plan, designed to cut emissions by 32 percent by 2030 and boost renewable energy use, has been thrown into legal limbo after the US Supreme Court ordered a stay of its implementation.




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Khaled Malallah Al Awadi, Energy Consultant MS & BS Mechanical Engineering (HON), USA Emarat member since 1990 ASME member since 1995 Hawk Energy member 2010

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Khaled Al Awadi is a UAE National with a total of 25 years of experience in the Oil & Gas sector. Currently working as Technical Affairs Specialist for Emirates General Petroleum Corp. “Emarat“ with external voluntary Energy consultation for the GCC area via Hawk Energy Service as a UAE operations base , Most of the experience were spent as the Gas Operations Manager in Emarat , responsible for Emarat Gas Pipeline Network Facility & gas compressor stations . Through the years, he has developed great experiences in the designing & constructing of gas pipelines, gas metering &

regulating stations and in the engineering of supply routes. Many years were spent drafting, & compiling gas transportation, operation & maintenance agreements along with many MOUs for the local authorities. He has become a reference for many of the Oil & Gas Conferences held in the UAE and Energy program broadcasted internationally, via GCC leading satellite Channels.

NewBase : For discussion or further details on the news above you may contact us on +971504822502 , Dubai , UAE

NewBase 03 April 2016 K. Al Awadi

new base 821 special 03 april 2016

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