New base 06 august 2018 no 1193 by khaled al awadi

Copyright © 2018 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 Energy News 06 August 2018 - Issue No. 1193 Senior Editor Eng. Khaled Al Awadi
NewBase For discussion or further details on the news below you may contact us on +971504822502, Dubai, UAE
UAE: DEWA tests energy storage systems at MBRM Solar Park
WAM/‫الشامسي‬ ‫سالمة‬/MOHD AAMIR + NewBase
Dubai Electricity and Water Authority, DEWA, has launched a pilot project to install and test a
1.2MW/7.2MWh Sodium Sulphur Battery Energy Storage System, NaS BESS, at the Mohammed
bin Rashid Al Maktoum Solar Park, the largest single-site solar park in the world.
The authority will connect the storage systems to its grid. The project in cooperation with Amplex
Emirates supports DEWA’s efforts to promote clean-energy production and storage technologies.
"DEWA is disrupting the business model of public utilities by creating a new digital future for Dubai
through Digital DEWA, its digital arm. DEWA will implement a leading model for utilities that is based
on innovation in renewable energy, energy storage, Artificial Intelligence, AI, and digital services.
DEWA will become the world’s first digital utility, using autonomous systems for renewable-energy
and storage, increasing the use of AI, and delivering digital services. It is just one of our projects to
support the Dubai Clean Energy Strategy 2050, to transform Dubai into a global hub for clean energy
and green economy, and provide 75 percent of Dubai’s total power output from clean energy by
2050," said Saeed Mohammed Al Tayer, MD and CEO of DEWA.

"Our initiative for Dubai 10X focuses
on four pillars to deliver a new utility
experience for Dubai and the world.
The first pillar is launching advanced
solar power technologies in Dubai,
and the second is deploying a
renewable energy grid that uses
innovative energy-storage
technologies.
This will make better use of the
diversified clean energy mix,
integrate renewables and storage,
and ensure maximum efficiency and
reliability of operations. The NaS
BESS project at the Mohammed bin
Rashid Al Maktoum Solar Park will
enable DEWA to evaluate the technical and economic capabilities and characteristics of this
technology when integrated with photovoltaic arrays, and see how it will increase network flexibility,"
added Al Tayer.
Al Tayer noted that DEWA is working on pilot energy storage systems. It is currently working on
NaS batteries from NGK that would result in the capacity of the battery reaching 6.25 megawatt
hours after 10 years.

Oman: New water desalination projects on anvil: Diam
Oman Observer - Conrad Prabhu
A string of new water desalination projects, currently under various stages of planning, tendering and
development at key locations across the Sultanate, will help supplant older, less efficient projects
nearing the end of their operational life, according to the Public Authority for Electricity and Water (Diam).
“Diam believes that desalination plants are the strategic choice for providing safe drinking water of high
quality and efficiency due to the geographical location of the Sultanate and the scarcity of groundwater
resources,” the state-owned utility said in a recent overview of its activities.
In all, a mammoth 650,000 cubic metres per day of new capacity will be added to Oman’s rapidly
burgeoning water desalination assets by the year 2023, according to Diam. Notable are two new
desalination plants planned in the wilayats of Jaalan Bani Bu Ali and Masirah Island in South Al
Sharqiyah Governorate by the year 2021.
The combined capacity of the two plants is estimated at 90,000 m3/day. In the Wilayat of Qurayat, a
plan to tap the large surface water reservoir created by the construction of Wadi Dayqah Dam will yield
a potable water supply of around 90,000 m3/day.
Of this volume, 67,000 m3/day is earmarked for distribution via Diam’s water distribution system while
the balance 23,000 m3/day will be allocated for agricultural and farming purposes, according to the
utility.
Also by 2022, Ghubrah in Muscat Governorate will add a gigantic 300,000 m3/day to its capacity in what
is set to be the largest water desalination investment. In the following year, Shinas on the North Al
Batinah coast will bring into operation a 150,000 m3/day capacity plant to meet potable water demand
growth in the governorate.
Khasab in Musandam Governorate will also feature its first Independent Water Project with a daily
production capacity of 16,000 cubic metres. The new capacity is envisioned in line with Diam’s vision
for achieving potable “water security and ensuring continuity of supply according to its long-term 2040
master plan”, said the utility.

Illustrating Oman’s transition to modern, energy efficient water projects are two world-class plants that
were brought into operation in Qurayat and Barka over the past year, according to Diam. While the
Qurayat project is contracted to supply 200,000 m3/day of potable water, the Barka facility — the largest
plant currently in operation in the Sultanate — has committed 281,000 m3/day of capacity.
“Both Barka and Qurayat desalination plants use reverse osmosis technology, which is one of the best
and most efficient desalination techniques in terms of cost of production, water quality and low
maintenance and use the latest world-class pressure regulator to reduce power consumption,” said
Diam.
“In addition, the reciprocating pumping system, between the main desalination plants, including Suhar,
Barka, Qurayat and Al Ghubrah plants, facilitates water transmission between the desalination plants
and the areas they serve through a central monitoring and control system, thus enhancing the efficiency
of the water security system in the Sultanate.”
Significantly, both plants are also equipped with dissolved air flotation (DAF) systems to combat plankton
and other impurities found in seawater linked to algal blooms and other natural phenomena. “These
plants operate with modern technology which enables them to work more effectively and efficiently and
under exceptional circumstances which water sources may be exposed to,” said Diam. “Moreover, these
plants have been built to replace the plants that are planned to go out of service in the coming years.”

Saudi Arabia resumes oil shipments through Bab-El- Mandeb
Reuters + NewBase
Saudi Minister of Energy, Industry and Mineral Resources Khalid Al-Falih, has announced
resumption of oil shipments through Bab-El- Mandeb Strait.
In a statement carried today by the Saudi Press Agency (SPA), Al-Falih, announced that Saudi
Arabia has resumed oil shipments through Bab-El-Mandeb Strait effective earlier today, after
confirmation by the Joint Forces of the Coalition to Restore Legitimacy in Yemen of taking necessary
measures to ensure the safety and security of the Coalition States' ships transiting through the strait
of Bab-El-Mandeb and the southern parts of the Red Sea, in coordination with the international
community and in accord with international law and related United Nations Security Council
resolutions.
Saudi Arabia had announced, on July 25, that oil shipments through Bab-El-Mandeb would be
temporarily halted after the unsuccessful terrorist attacks carried by Iran-supported Houthi Militia on
two Saudi crude carriers.
The Bab al-Mandeb strait, where the Red Sea meets the Gulf of Aden in the Arabian Sea, is only
20 km (12 miles) wide, making hundreds of ships potentially easy targets. After Saudi’s decision to
halt shipments, Yemen’s Houthi group said on July 31 it would halt attacks in the Red Sea for two
weeks to support peace efforts.
The Saudi coalition intervened in Yemen’s civil war in 2015 to restore the internationally recognized
government of exiled president Abd-Rabbu Mansour Hadi.
Minister Khalid Al-Falih said: "The decision to resume oil shipment through the strait of Bab-El-
Mandeb was made after the leadership of the Coalition has taken necessary measures to protect
the Coalition States' ships."

He also expressed his confidence that the Kingdom-led Coalition has made all necessary security
measures, in coordination with the international community, to minimize the risks which may
threaten the Coalition States' ships that are navigating through the strait of Bab-el-Mandeb and the
southern portion of the Red Sea, thus ensuring a continuous supply of energy to the world in
accordance with the highest security standards and precautions.
He also emphasized that
the security of the strait of
Bab-El-Mandeb and the
southern parts of the Red
Sea is a joint international
interest, towards which the
whole international
community should uphold
its responsibilities.
The statement of the
Minister came after a
statement issued recently
by the spokesperson of the
Coalition Forces in which he
confirmed that the Coalition
Forces carried out an
overall evaluation of the Houthi Militia attacks, which targeted the freedom of navigation through
Bab-El-Mandeb, and that all necessary measures were taken to secure maritime navigation and
international trade through the strait.

Indonesia: Empyrean Energy operations update on Mako gas discovery
Empyrean Energy, the oil and gas development company with interests in China, Indonesia and the
United States, has been informed by Conrad, its partner in the Duyung PSC, offshore Natuna Basin
- Indonesia on progress at the Mako Gas Discovery. The Duyung PSC is 100% held by West
Natuna Exploration Limited ('WNEL'). Empyrean is a 10% shareholder in WNEL with Conrad owning
the remaining 90%.
Highlights
 Plan of Development for the Mako Gas Field ('Mako POD') submitted to SKKMigas, the Indonesian
oil and gas regulator
 Heads of Agreement ("HOA") signed with a regional gas buyer for the sale of all Mako gas
 Indonesian Government owned and accredited consultant, Lemigas, were contracted to certify initial
reserves and assist with POD work and submission
 Concurrently, Conrad Petroleum has completed a preliminary internal estimate of 2C Contingent
Resources of 373Bcf based on gas sales to be sold within the Duyung PSC term of the full Mako Gas
Field
 Lemigas certified 2P 'Reserves'* of 152.30Bcf gas based on Mako South-1 gas well only
 Further appraisal wells are planned to lift the Lemigas certified Resources to reflect the potential of
the full Mako Gas Field
 Strong unsolicited third-party interest shown in participating in the Duyung PSC pre-POD
 High Impact Exploration 'leads' identified below the Mako Gas Field ('Mako Deep')
Conrad has advised Empyrean that WNEL has submitted the Mako POD to SKKMigas, the
Indonesian oil and gas regulator, which will, in turn recommend the Mako POD to the Indonesian
Ministry of Energy and Mines. The Indonesian Ministry of Energy and Mines is expected to approve
the POD during Q4 2018. WNEL contracted Indonesian Government owned and accredited

consultants, Lemigas, to work on preparation and submission of the POD and to help ensure that
all SKKMigas and Indonesian Ministry of Energy and Mines requirements were substantially met.
The Mako POD approval process paves the way for the Duyung PSC to convert into a Production
Permit through to 2037 following approval of the Mako POD.
As part of the initial Mako POD submission, WNEL has negotiated and reached a HOA for the sale
of all Mako gas to a regional utility. The final terms and pricing will be contained in a Gas Sales
Agreement ('GSA') to be negotiated between the parties
As part of the POD submission, Lemigas completed a certification of reserves based primarily on
the Mako South-1 well and an area of circumference spreading out from the well. In addition,
Conrad has completed an internal calculation of its contingent resources based on the full Mako
Gas Field.
The Conrad preliminary estimate of 2C Contingent Resources of 373Bcf is expected to be converted
into reserves following a Final Investment Decision ('FID') by WNEL and the signing of a GSA and
agreements to access the West Natuna Transport System ('WNTS'), the pipeline that carries gas to
mainland Singapore. Conrad also has plans for third party certification of its Contingent Resources
using current Society of Petroleum Engineers ('SPE') standards in due course. The 'Lemigas
Reserves' are shown in the table below:
* It is important to note that
'reserves' in this context does not
equate with the current SPE
definitions followed by Conrad but
does signify approval for WNEL to
extract the certified volume of gas.
Work on the FID, GSA and Access
Agreements is a priority for WNEL
in the coming 12 months.
Recently completed re-processing
of 2009 vintage 2D seismic data
utilising the latest advanced
techniques has substantially improved imaging of the geological features underneath the Mako Gas
Field. Ongoing evaluation of this data has identified a significant exploration 'lead', named Mako
Deep.
Whilst Mako Deep is named due to its proximity below the Mako Gas Field, it is in fact relatively
shallow by industry standards at 2000-6000ft below mean sea level. Mako Deep is likely to contain
well developed thick sand packages as proven by the Tengirri-1 well (drilled by Conoco in 1975).
Provisional initial estimates show that Mako Deep has the potential to contain very large quantities
of recoverable hydrocarbons, both oil and natural gas. Seismic interpretation, and analysis of the
cuttings of the old Tengirri well are underway to further delineate and de-risk this exciting 'lead' for
potential future drilling that could be executed sometime during 2019.
Following a technical presentation by Conrad in London recently and in the lead up to the
submission of the POD to SKKMigas, there has been several approaches by third parties interested
in participating in the Duyung PSC. Whilst no transactions have been concluded, the level of interest
in the Mako Gas Field is encouraging.

China tariffs on LNG, oil aim at U.S. energy dominance agenda
Reuters - Scott DiSavino, Chen Aizhu
China’s proposed tariffs on U.S. liquefied natural gas and crude oil exports opens a new front in the
trade war between the two countries, at a time when the White House is trumpeting growing U.S.
energy export prowess.
China included LNG for the first time in its list of proposed tariffs on Friday, the same day that its
biggest U.S. crude oil buyer, Sinopec, suspended U.S. crude oil imports due to the dispute,
according to three sources familiar with the situation.
On Friday, China announced retaliatory tariffs on $60 billion worth of U.S. goods, and warned of
further measures, signaling it will not back down in a protracted trade war with Washington.
That could cast a shadow over U.S. President Donald Trump’s energy dominance ambitions. The
administration has repeatedly said it is eager to expand fossil fuel supplies to global allies, while
Washington is rolling back domestic regulations to encourage more oil and gas production.
“The juxtaposition here is clear: it is hard to become an energy superpower when one of the biggest
energy consumers in the world is raising barriers to consume that energy. It makes it very difficult,”
said Michael Cohen, head of energy markets research at Barclays.
The United States is the world’s largest exporter of fuels such as gasoline and diesel, and is poised
to become one of the largest exporters of LNG by 2019. U.S. LNG exports were worth $3.3 billion
in 2017. China is the world’s biggest crude oil importer.

China had curtailed its imports of U.S. LNG over the last two months, even before its formal inclusion
in the list of potential tariffs. It had also become the largest buyer of U.S. crude oil outside of Canada,
but Kpler, which tracks worldwide oil shipments, shows crude cargoes to China have also dropped
off in recent months.
It comes at a time when the United States has several large-scale LNG export facilities under
construction, and after Trump’s late 2017 trip to China that included executives from U.S. LNG
companies.
China became the world’s second-biggest LNG importer in 2017, as it buys more gas in order to
wean the country off dirty coal to reduce pollution.
“This will not affect the trade but will simply make gas more expensive to Chinese consumers,” said
Charif Souki, chairman of Tellurian Inc (TELL.O), one of several companies seeking to build a new
LNG export terminal.
China, which purchased almost 14 percent of all U.S. LNG shipped between February 2016 and
May 2018, has taken delivery from just one vessel that left the United States in June and none so
far in July, compared with 17 in the first five months of the year.
“The U.S. gas industry will be much harder hit by this as China imports only a small volume whereas
U.S. suppliers see China as a major future market,” said Lin Boqiang, professor on energy studies
at Xiamen University in China.
Meanwhile, according to Kpler, crude exports to China dropped to an estimated 226,000 barrels per
day (bpd) in July, after reaching a record 445,000 bpd in March. Sinopec, through its Unipec trading
arm, is the largest buyer of U.S. crude.
China would likely hike purchases from Saudi Arabia, Russia, the United Arab Emirates and Iraq if
the tariffs slowed U.S. flows, said Neil Atkinson, head of the oil industry and markets division at the
International Energy Agency.

There will be “others who will be offering barrels to China, so it could find itself able to replace lost
volumes from the U.S.,” Atkinson said.
With LNG demand expected to skyrocket over the next 12 to 18 months, there are still some two
dozen firms seeking to build new LNG export terminals in the United States and tariffs may limit
their ability to secure sufficient buyers to finance their proposed projects.
“Cheniere continues to see China as an important growth market and LNG as a ‘win-win’ between
the United States and China,” said Eben Burnham-Snyder, a spokesman at Cheniere Energy Inc
(LNG.A), which owns one of the two LNG export terminals currently operating in the United States.
He added they do not see tariffs as productive.
One project being developed is in Alaska, which would carry natural gas through an 800-mile (1,287
km) pipeline across the state to a terminal that would convert it to LNG to take it to China.
The $43 billion project is still in development, and the Alaska Gasline Development Corp said on
Friday that it believes the “current trade tensions between the United States and China will be
resolved well in advance of Alaska LNG exports to China.”

U.S. coal shipments reach their lowest levels in years
Source: U.S. Energy Information Administration, Coal Transportation Rates to the Electric Power Sector
The 661 million short tons (MMst) of coal consumed in the electric power sector in 2017 was the
lowest amount of coal consumed since 1983, and 2017 was the fourth consecutive year that U.S.
coal consumption and coal shipments by all transport modes declined. Nearly 70% of the coal
consumed in the power sector in 2017 was shipped either completely or in part by rail, with the
remainder shipped by river barge, truck, and other methods.
Electric power sector coal consumption in 2017 was 36% (376 MMst) lower than in 2008, when U.S.
coal production reached its highest level. The amount of coal shipped by rail has similarly declined:
432 MMst of coal were shipped by rail in 2017, a slight increase from 2016 but 33% lower than the
647 MMst shipped by rail in 2008.
The share of coal shipments made by river barge has increased from 7% (2008) to 12% (2017).
Coal produced in the Illinois Basin relies on shipments along the Ohio River and its tributaries for a
significant share of its production.
The share of shipments made by truck has gone from 12% (2008) to 9% (2017), coinciding with
declines in Appalachian production that supplied generating facilities—many of which have closed
or reduced their consumption of coal—that were a relatively short distance from the mines.

The cost of transporting coal can vary greatly along different routes. In addition to costs associated
with a particular mode of transport, factors such as route length, availability of transport mode,
supply source options, and the competition between coal and other commodities for transport can
affect the transportation cost.
The real delivered cost of coal for all transport modes (commodity cost plus transportation cost) has
fallen in recent years, most recently lower than $40 per ton in 2017, based on preliminary EIA
estimates.
The real delivered cost of coal has fallen nearly $8.00 per ton (16%) since 2008, with most of the
reduction attributable to declining commodity costs. Over that same period, overall coal
transportation costs have fallen by 4%, as declines in truck (down 9%) and river barge (down 39%)
costs more than offset a 3% increase in rail shipping costs. EIA's updated tables average costs per
ton by mode and by year on a coal basin-to-state basis and on a state-to-state basis.
EIA’s updated summary of coal transportation rates through 2016 show the average real costs per
ton of transporting coal from mines to power plants by mode based on data reported by plant owners
and operators to EIA on the Power Plant Operations Report.
More information from EIA’s coal and electricity industry surveys is available in the interactive coal
data browserand electricity data browser.

NewBase August 06 - 2018 Khaled Al Awadi
NewBase For discussion or further details on the news below you may contact us on +971504822502 , Dubai , UAE
U.S. oil drillers cut rigs for second week in three: Baker Hughes
U.S. energy companies this week cut oil rigs for a second time in the past three weeks as the rate
of growth has slowed over the past couple of months with recent declines in crude prices.
Drillers cut two oil rigs in the week to Aug. 3, bringing the total count down to 859, General Electric
Co’s Baker Hughes energy services firm said in its closely followed report on Friday.
More than half the total oil rigs are in the Permian basin in west Texas and eastern New Mexico,
the nation’s biggest shale oil field. Active units there held steady at 479 for a second week in a row,
the same as in early June and the highest since January 2015.
The U.S. rig count, an early indicator of future output, is higher than a year ago when 765 rigs were
active as energy companies have been ramping up production in anticipation of higher prices in
2018 than previous years.
Analysts at Simmons & Co, energy specialists at U.S. investment bank Piper Jaffray, this week
forecast average total oil and natural gas rig count would rise from 876 in 2017 to 1,032 in 2018,
1,092 in 2019 and 1,227 in 2020. That compares with their forecast last week of 1,033 in 2018,
1,092 in 2019 and 1,227 in 2020.
Oil price special
coverage

Since 1,044 oil and gas rigs were already in service, drillers would only have to add a handful of
rigs during the rest of the year to hit Simmons’ forecast for 2018.
So far this year, the total number of oil and gas rigs active in the United States has averaged 1,010.
That keeps the total count for 2018 on track to be the highest since 2014, which averaged 1,862
rigs. Most rigs produce both oil and gas.

NewBase Special Coverage
News Agencies News Release August 06-2018
World Energy Investment 2018
Investing in our energy future
"The decline in global investment for renewables and energy efficiency combined could threaten
the expansion of clean energy needed to meet energy security, climate and clean-air goals. While
we would need this investment to go up rapidly, it is disappointing to find that it might be falling this
year.” Fatih Birol, Executive Director, IEA
The IEA's World Energy Investment provides a wealth of data and analysis for decision making by
governments, the energy industry and financial institutions to set policy frameworks, implement
business strategies, finance new projects and develop new technologies. It highlights the ways in
which investment decisions taken today are determining how energy supply and demand will unfold
tomorrow.
This year's edition points to another year of falling investment in 2017, and that energy investment
is failing to keep up with energy security and sustainability goals.
Findings
Total energy investment has fallen again...
2017 was the third consecutive year of decline in global energy investment with energy efficiency
the lone sector of growth. Despite a 6% decline in spending, the electricity sector again attracted
the largest share of energy sector investments, exceeding the oil and gas industry for the second
year in row, as the energy sector moves toward greater electrification.

and is increasingly underpinned by governments
State-backed investments are accounting for a rising share of global energy investment, as state-
owned enterprises have remained more resilient in oil and gas and thermal power compared with
the private sector.
The share of global energy investment driven by state-owned enterprises increased
over the past five years to over 40% in 2017.
Government policies are playing a growing role in driving private spending
Across all power sector investments, more than 95% of investment is now based on regulation or
contracts for remuneration. Investment in energy efficiency is particularly linked to government
policy, often through energy performance standards.

The power sector is becoming more capital intensive
Electricity investment has shifted towards renewables, networks and flexibility. Yet, renewable
power investment declined in 2017 by 7%, despite record levels of spending on solar PV.
Moreover, the expected output from low-carbon power investments fell 10% in 2017 and did not
keep pace with demand growth.
In emerging markets, auctions are supporting larger renewable projects
In emerging markets the average size of awarded solar PV projects in auctions rose by
4.5 times while that of onshore wind rose by half over 2013-17, helping to support
economies of scale. In Europe, tendered large projects are mainly concentrated in
offshore wind; auctions have generally not resulted in large, land-based renewables
projects.

Fewer decisions are being taken for investment in thermal generation
In 2017 newly sanctioned coal power fell 18%, driven by a slowdown in China, India and Southeast
Asia. However, despite declining capacity additions - and a wave of retirements of existing plants -
the global coal fleet continued to expand in 2017. And while investment decisions signal a continued
shift towards more efficient plants, 60% of currently operating capacity uses inefficient subcritical
technology. Meanwhile, sanctioned gas power fell nearly 23%, due mainly to the MENA region and
the United States.
Thermal generation capacity subject to a final investment decision by plant type
Oil and gas companies are doing more with less ...
Following the peaks in oil and gas upstream investment reached in 2014, investment collapsed abruptly as
a result of lower prices. 2017 investment rebounded by 2% in real terms, and we estimate the same level of
growth for 2018.
One notable trend concerns the relationship between oil prices and upstream costs. In the past, there has
been a roughly linear relationship between upstream costs and oil prices. When price spiked, so did costs,
and vice versa. What we are noting now is a decoupling. While prices have more than doubled since 2016,
global upstream costs have remained substantially flat and for 2018 we estimate those increasing very
modestly, by just 3%. Companies appear to have learned to do more with less.

... and the dynamics of the oil and gas industry are evolving
The oil and gas industry has been traditionally characterised by long-lead times projects with
predictable production profiles. Yet as a result of the shale revolution in the United States this trend
is changing and the industry is re-thinking the way they choose, execute and manage projects.
Furthermore, investment in conventional assets (responsible for the bulk of supply) remains focused
on expansion of existing projects rather than developing new sources of production.
Moving forward, the overall balance of market supply will be given by combination of conventional
activities (which respond slowly) and unconventional projects (which respond to market conditions
in a much more rapid way) suggesting the possibility of more volatility ahead in the markets.
Meanwhile, US LTO is becoming a financially sustainable business
The prospects of the US shale industry are improving. Between 2010 and 2014, companies spent up to
USD 1.8 for each dollar of revenue. However, the industry has almost halved its breakeven price, providing
a more sustainable basis for future expansion. This underpins a record increase in US light tight oil
production of 1.3 million barrels a day in 2018.

Clean energy R&D investment is finally on the rise
Government low-carbon energy RD&D spending in 2017 was estimated to have increased by 13%
in 2017. This is a welcome increase after years of decreases and stagnation. Much of the increase
in low-carbon energy technology RD&D spending is driven by North America, more than
compensating for declines in Europe and Japan.
Yet investment in carbon capture, utilisation and storage is falling behind
Commercial incentive as low as USD 40 per tonne of CO2 sequestered could trigger investment in
the capture, utilisation and storage of up to 450 million tonnes of CO2.

ICT appears to be banking on the energy sector
Corporate investments in new energy technology companies are growing strongly, reaching their
highest ever level of just over USD 6 billion in 2017 - strategic investments by companies to get a
stake in potentially key new technology areas.
While there is some increase in investments by utilities, the striking finding is that vast majority of
the growth is coming from ICT companies, mostly investing in EV start-ups and digital solutions for
smart grids and efficiency.
2017Corporate investments in new energy technology companies, by

NewBase For discussion or further details on the news below you may contact us on +971504822502, Dubai, UAE
The Editor :”Khaled Al Awadi” Your partner in Energy Services
NewBase energy news is produced daily (Sunday to Thursday) and
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Khaled Malallah Al Awadi,
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Khaled Al Awadi is a UAE National with a total of 28 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.
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