New base energy news 06 october 2020 issue no. 1379 by senior editor khaled alawadi

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NewBase Energy News 06 October 2020 - Issue No. 1379 Senior Editor Eng. Khaled Al Awadi
NewBase for discussion or further details on the news below you may contact us on +971504822502, Dubai, UAE
U.A.E:Dubai launches first association of district cooling operators
WAM/Hassan Bashir ( images by NewBase)
The Vice Chairman of Dubai Supreme Council of Energy, DSCE,(Saeed Mohammed Al Tayer)
announced that Dubai has launched the region’s first Association of District Cooling Operators to
enhance the efficiency of district cooling operations and optimise water and energy resources.
"The DSCE achieves the strategic objectives of the Demand Side Management Strategy to reduce
30% of the electricity and water demand by 2030.
This is in accordance with the vision of His Highness Sheikh Mohammed bin Rashid Al Maktoum,
Vice President and Prime Minister of the UAE and Ruler of Dubai, to enhance the shift towards a
sustainable green economy. We are working on 11 programmes to manage the demand on water
and energy, including Green Building Code; Building Retrofits; Outdoor Lighting and Efficient
Cooling," said Al Tayer.
"The district cooling systems and technologies which have been deployed across the UAE that
reduce by half, the energy used for cooling. This supports Dubai’s efforts to reduce its carbon
footprint. We have achieved significant success in the Dubai Carbon Abatement Strategy by
reducing more than 14 million tonnes of emissions in 2019. This is equal to a 22% reduction
compared to business as usual. Results achieved exceeded the targets set in the Dubai Carbon
Abatement Strategy, which aims to reduce carbon emissions by 16% by 2021," added Al Tayer.
www.linkedin.com/in/khaled-al-awadi-38b995b

Ahmad Bin Shafar, CEO of Emirates Central Cooling Systems Corporation (EMPOWER), presided
over the association’s first meeting in the presence of Ahmad Buti Al Muhairbi, Secretary General
of the DSCE.
Representatives from the DSCE and the Regulatory and Supervisory Bureau for Electricity and
Water of Dubai (RSB) attended the meeting.
At the beginning of the meeting, Bin Shafar welcomed the attendees and thanked the Dubai
Supreme Council of Energy for their support to launch the association, which is the first of its kind
in the region.
"The association, which is an official and recognised platform, aims to raise the efficiency of district
cooling plants and create a roadmap to improve water and electricity consumption in operations by
sharing local expertise in the district cooling sector, in line with the best international practices," said
Bin Shafar.
Al Muhairbi outlined the need to increase the penetration of district cooling in Dubai to reach 40%
by 2030. He also extended his full support to the association. he said that district cooling operators
should integrate modern technologies of energy efficiency into their operations and prioritise the
usage of recycled water in district cooling.
"The DSCE aims to strengthen collaboration among members to support energy efficiency
initiatives. I encourage everyone to take part in outlining best practices for promoting district cooling
as a desiredcooling option in Dubai," he concluded.

Saudi Oil Surge in Flows Offset Cut in UAE’s September Exports
By Julian Lee
Saudi Arabia increased oil shipments in September, offsetting lower flows from the United Arab
Emirates as the smaller nation started to compensate for earlier over-production, and leaving
exports from OPEC’s Middle East producers broadly stable for a third month.
Exports from Saudi Arabia rose by more than 480,000 barrels a day, almost exactly offsetting the
drop in shipments from the UAE last month. Kuwait and Iraq increased flows by smaller amounts.
The four nations shipped a total of 13.61 million barrels a day of crude and condensate last month,
up by 164,000 barrels a day from August, tanker-tracking data monitored by Bloomberg show.
Flows from the four producers -- which account for more than 70% of production among members
of the Organization of Petroleum Exporting Countries -- rose to South Korea, but shipments to all
other major buyers including China were down, based on preliminary indications of ship
destinations.
Observed flows from Iran have been excluded, as tankers often disappear from tracking for weeks.
With more than 20 million barrels of oil on ships yet to signal a final destination, estimates of flows
to individual countries are subject to potentially large revisions.
Shipments to South Korea rebounded to the average level seen during the 12 months through
March, before the second quarter surge and subsequent slump. Saudi Arabia, the UAE and Kuwait
all boosted flows, lifting shipments by a combined 350,000 barrels a day, more than twice the size
of the drop in exports from Iraq.

Aggregate Arabian Gulf crude flows to India edged lower in September, as refinery runs in their
closest major market remained subdued amid anaemic diesel demand. Shipments were about
460,000 barrels a day, or 17%, below the average seen in the 12 months through April.
Flows to the U.S. continued their slide, falling below 250,000 barrels a day. Just one Suezmax
tanker, carrying 1 million barrels of crude, left Iraq for the U.S. last month. Shipments from Saudi
Arabia fell to 183,000 barrels a day in September from a revised 242,000 barrels a day in August.

A surge in shipments to China from Iraq and Kuwait was more then offset by lower flows from Saudi
Arabia and the UAE, leaving preliminary estimates of the volume of crude sent to the Asian nation
down by 100,000 barrels a day compared with the revised August figure.
Crude and condensate flows to Japan edged lower in September, with an increase of 100,000
barrels a day from Kuwait more than offset by similar sized declines from both Saudi Arabia and the

UAE. Overall flows remained almost 700,000 barrels a day, or nearly 30%, below first-quarter levels,
before the Covid-19 pandemic slashed demand.
Note: The figures above include exports from northern Iraq via Ceyhan in Turkey and outflows from
the UAE’s Indian Ocean coast and from Saudi Arabian Red Sea ports. They include crude and
condensates, a light form of oil extracted from gas fields. Figures for flows to individual destinations
are subject to change, especially when ships pass transit points like Singapore and the Suez Canal.

Oman expects $B30 investment in clean energy projects by 2030
By Sowmya Sundar, ZAWYA
Oman is looking at an investment of $30 billion in clean energy projects by 2030, a senior official at
Ejaad, an Omani think tank, said.
“We foresee 30 gigawatts (GW) collective renewable capacity potential for hydrogen, heat
substitution, and industrial projects by 2030. This translates into a $30-billion investment by 2030,”
said Abdullah Al-Abri, Manager at Ejaad, an organisation that is involved in energy-related research
and innovation activities.
“The government has decided to take a
deep dive into hydrogen. A consortium of
more than 30 stakeholders are participating
in a feasibility study to look at how we can
develop a hydrogen economy in Oman and
look at policies and enabling factors”, Al-
Abri said, speaking at an online panel
discussion titled, “Oman: A promising
destination for clean energy”, which was
organised by Ejaad and International
Energy Agency (IEA).
Al-Abri said Oman has promising potential
for renewable energy substitution across
three verticals – electricity generation,
Power-to-X, and industry.
The strategy will revolve around using
cheap electricity from renewables to
replace gas-fired plants for Oman’s core
electricity system; exploring Power-to-X opportunities including using green hydrogen for industry,
steam generation for enhanced oil recovery and heat substitution; and finally, capitalising cheap
renewable electricity costs to attract new energy-intensive industries such as data centres and
smelters.
Business case for green hydrogen
Around 95 percent of the global demand for industrial hydrogen is refining, ammonia, and methanol
plants. Therefore, the global demand for hydrogen is expected to rise in line with the demand for
ammonia and methanol and stricter desulphurisation requirements in the refinery sector, he said in
his presentation.
Middle East hydrogen consumption had gone up from 66,789 million cubic metres in 2014 to 89,161
million cubic metres in 2019.
“Oman is already a producer of ammonia and methanol, and there are refining units across the
GCC. Currently, the hydrogen is produced from natural gas. By 2030, Oman is looking at more than
10 GW of installed renewable energy potential to produce hydrogen for industry through renewable-
powered electrolysis and another 9-10 GW for process heat substitution projects,” Al-Abri said.
“We have marked out all the heat requirements in industrial processes and classified heat
requirements into low, high, mid, and very high temperatures. This will help us identify where we

can best use hydrogen for heat substitution. Currently, most existing technologies are suitable for
lower to mid-range heat requirements,” he said.
Elaborating on the business case for green hydrogen in Oman, he said it is now expensive
compared to hydrogen produced from natural gas, but the cost of producing green hydrogen is
expected to fall going forward.
“For example, replacing existing steam methane reforming with new electrolysers and photovoltaic
solar panels becomes economical at a levelized cost of $718 per metric tonne of hydrogen from
2023 onwards. So, if we start a big project today, by the time we complete the FEED and design
and start procuring electrolysers, we are in the money,” he said.
“Four key points are essential to
driving the development and
localisation of hydrogen and
renewables at large - A clear
development vision with a multi-year
journey to be taken in steps,
strategic international partnerships,
de-risk investments to achieve
superior economics and local
content requirements focusing on
true localisation and not just
compliance,” Al-Abri concluded.

Pakistan: Siemens Gamesa to construct 8 wind farms 410 MW
Siemens + NewBase
Siemens Gamesa, s a global leader in the wind power industry, has secured a series of orders for
eight new wind farms in Pakistan during the company’s 2020 fiscal year, totalling 410 MW. These
projects will position the company as one of the leading players in Pakistan’s nascent wind energy
market.
The central Asian country is rigorously building out electricity generating capacity, battling power
blackouts. Partnering with an Engineering, Procurement and Construction (EPC) contractor,
Siemens Gamesa will supply, install and commission a total of 205 units of Siemens Gamesa 2.X
turbines for eight projects with a combined capacity of 410 MW.
Of the eight wind farms package, two projects have already started construction, with
commissioning expected in November 2020 and February 2021 respectively.
When fully operational at the end of 2021, these eight wind farms will generate enough electricity to
cover the annual needs of up to 600,000 local households with clean and affordable electricity,
significantly alleviating the power shortage in Pakistan where 40 million residents have no access
to electricity supply.
“As a global pioneer of wind solutions, Siemens Gamesa has a track record of bringing innovative
technologies to developing markets across the globe. We’re pleased with the impact and
partnership we have been able to make in Pakistan,” said Enrique Pedrosa, Chief Regions Officer
of Siemens Gamesa’s Onshore business unit.
“Renewables are at the centre of the global energy transition and will play an essential role in
economic recovery post Covid-19. We’re well positioned and committed to bringing more
sustainable and affordable clean energy for generations to come in Pakistan,” he added.
Siemens Gamesa has grown in the Asia Pacific region since the 1980s and has now installed more
than 8.5 GW of onshore turbines in China, Pakistan, Japan, South Korea, Vietnam, Indonesia, the
Philippines, Thailand, Australia and New Zealand. On the offshore side, the company completed
the installation of Taiwan’s first offshore wind power project in 2019 (128 MW) and in addition
reached close to 2 GW of firm orders in the island. –

US oil refiners look to leapfrog Canadians in making renewable diesel
Reuters + NewBase
US oil refineries are moving aggressively to produce renewable diesel, partly to cash in on Canada’s
greener fuel standard before Canadian refiners modify their own plants. Canadian Prime Minister
Justin Trudeau’s government intends to present its Clean Fuel Standard this year, aiming to cut 30
million tonnes of emissions by 2030.
Renewable diesel, made by processing spent cooking oil, canola oil or animal fats, can be used in
high concentrations or without blending in conventional diesel engines.
So far, Canadian companies have been slow in preparing to make the fuel, with only three projects
publicly announced, said Ian Thomson, president of the Advanced Biofuels Canada industry group.
At least five US refiners have announced plans to produce renewable diesel or said they are
considering it, including Phillips 66 and HollyFrontier Corp.
“This is Canada’s to lose,” Thomson said. “If Canada’s refiners want to get left out of the game, they
will dig their heels in and oppose the standard. Meanwhile, the Americans will build.”
Renewable diesel is a niche market, making up just 0.5 per cent of the 430-billion gallon per year
global diesel market, according to investment bank Morgan Stanley.
Greenhouse gas emissions from renewable diesel and traditional biodiesel are typically 50 per cent
to 80 per cent lower than conventional diesel.
US states such as Colorado and Washington are moving toward such standards and along with
Canada’s fuel standard, a sufficient market is developing, said HollyFrontier executive Tom Creery,
on the company’s second-quarter earnings call.
Suncor Energy Inc, Canada’s second-biggest oil producer, has been considering a renewable diesel
plant in Montreal, but the pandemic slowed its progress, said Chief Sustainability Officer Martha
Hall Findlay.
Canadian refiners face longer regulatory delays than competitors in the United States, setting them
at a disadvantage, she said.

“The timelines would force investment in facilities outside Canada because of the sheer fact that we
can’t build them that fast,” Hall Findlay said.
Parkland Fuel Corp is producing renewable diesel and renewable gasoline in its Burnaby, British
Columbia refinery, and is considering expanding capacity, said Senior Vice-President Ryan
Krogmeier. “There’s a tremendous opportunity for Canada to harness its natural resources,” he said.
“The market for renewable fuels is really taking off.”
About:- PETROLEUM. BIODIESEL. RENEWABLE. WHAT’S THE DIFFERENCE?
1. Petroleum diesel: The traditional fuel source diesel engines were built to run on, but also the
largest contributor to emissions pollution.
2. Biodiesel: is a fuel made from agricultural products. While less harmful than petroleum, it
requires a blend with petroleum diesel to properly function in diesel engines, which undercuts its
environmental benefits.
3. Renewable diesel: is a fuel primarily composed of biomass waste and residue. The composition,
life cycle emissions reductions, and compatibility within diesel engines make this fuel a leading
alternative to petroleum diesel.

October 06-2020 Khaled Al Awadi
NewBase for discussion or further details on the news below you may contact us on +971504822502, Dubai, UAE
Oil holds gains (yesteday’s 5%) after Trump's return to White House
Reuters + NewBase
Oil prices edged higher in early trade on Tuesday after U.S. President Donald Trump returned to
the White House from hospital after being admitted for treatment for COVID-19 last Friday, while
another storm brewed in the U.S. Gulf of Mexico.
Prices fell sharply last Friday when Trump went into hospital, then climbed more than 5% on Monday
after he said he would return to the White House and as hopes grew that a deal could be agreed
for a U.S. economic stimulus package to counter the impact of the coronavirus pandemic.
U.S. West Texas Intermediate (WTI) crude CLc1 futures rose 23 cents to $39.45 a barrel at 5.40
GMT. Brent crude LCOc1 futures rose 26 cents, or 0.63%, to $41.55 a barrel.
An expanding strike by workers in Norway, which shut six offshore oil and gas fields, and the
evacuation of oil platforms in the U.S. Gulf of Mexico ahead of Tropical Storm Delta heading toward
Louisiana and Florida also helped support prices.
Oil price special
coverage

“It’s the supply-side factors that have changed in the last 24 hours and are contributing more to the
uplift,” said Lachlan Shaw, head of commodity research at National Australia Bank.
The Norway strike will cut the country’s total output capacity by just over 330,000 barrels of oil
equivalent per day, or about 8% of total production, according to the Norwegian Oil and Gas
Association.
Meanwhile hopes for a bipartisan U.S. economic relief package grew as House Speaker Nancy
Pelosi and Treasury Secretary Steven Mnuchin spoke on Monday and prepared to talk again
Tuesday, continuing a recent flurry of activity working towards a deal on legislation.
“There’s better (fuel) demand sentiment surrounding the potential for U.S. fiscal agreement, and
perhaps President Trump leaving hospital might drive a bit of impetus to conclude a deal there,”
Shaw said.
Data from the American Petroleum Institute on Tuesday and the U.S. government on Wednesday
will provide a picture of whether demand is picking up.
Five analysts polled by Reuters estimate, on average, that crude stocks rose by 400,000 barrels in
the week to Oct. 2, while gasoline inventories likely fell by 900,000 barrels and distillate stockpiles,
which include diesel and heating oil, likely dropped by 1.4 million barrels.

Saudi Arabia Pegs Budget to Oil at Around $50, Goldman Says
Bloomberg - Abeer Abu Omar
Saudi Arabia’s Finance Ministry is budgeting for oil prices to be around $50 a barrel for the next
three years, according to a Goldman Sachs Group Inc. analysis of the kingdom’s fiscal plans.
“Using our own estimates for the breakdown of government revenues, we calculate that the numbers
presented in the budget statement are based on an average oil price of around $50 a barrel between
2020 and 2023,” said Farouk Soussa, a London-based analyst at Goldman, referring to a pre-budget
statement from Sept. 30.
Brent crude fell 6.3% to $39.27 a barrel last week as more countries tightened restrictions to counter
the coronavirus pandemic and U.S. President Donald Trump got infected, causing traders
to fret about the outlook for energy demand.
Oil Realism
While oil at $50 would represent a 25% rise from current prices, it would still be far below the pre-
pandemic level of around $65 and less than Saudi Arabia needs to balance its budget.
Goldman’s calculations are roughly in line with those of Cairo-based investment bank EFG Hermes,
which said Saudi Arabia is basing next year’s budget on an oil price of $50 to $55. Goldman is itself
more bullish, forecasting that Brent will climb to $65 by the end of 2021.
Saudi officials expect the country’s fiscal deficit to narrow to 5.1% of gross domestic product in
2021 from 12% this year as they cut spending, according to last week’s statement.

The kingdom tends to take a relatively conservative view of crude prices in drawing up its budget
and doesn’t divulge its assumptions, leaving analysts to estimate them from other projections. The
Finance Ministry didn’t immediately respond to a request for comment on Sunday.
Saudi Arabia would need oil to trade at $66 to balance its budget in 2021, according to estimates
from the International Monetary Fund.
IMF BREAKEVEN OIL PRICES IN $/BARREL (AS OF APRIL 2020):
Saudi Arabia’s caution on prices comes as oil giants including BP Plc and Total SE predict the era
of growing global demand for energy is over or coming to an end barely a decade from now.
That’s especially a concern for countries such as Saudi Arabia, where oil accounted for nearly two-
thirds of government revenue in 2019. In the second quarter, Saudi earnings from crude
exports dropped to the lowest on a quarterly basis since at least 2016, despite the kingdom leading
OPEC’s efforts since May to cut supply and bolster prices.
“It seems they are assuming some pick-up next year, but oil income will be flat between 2021 and
2022, and will only start to pick up again in 2023,” said Mazen Al-Sudairy, head of research at Al
Rajhi Capital.

NewBase Special Coverage
The Energy world – October 031- September -2020
Op-ed: A $100 billion Big Oil divestiture plan is coming
CNBC- Tore Guldbrandsøy, senior vice president, and Ilka Haarmann, analyst, at Rystad Energy
The largest oil and gas companies, including ExxonMobil, Royal Dutch Shell, Chevron and BP, are
projected to sell a combined $100 billion in oil and gas assets around the world as they focus on
top-performing regions, particularly the U.S. shale, according to a new analysis from consulting firm
Rystad Energy.
Climate change and renewable energy investments are forces that these Big Oil firms need to
respond to strategically, but their own carbon divestiture campaigns will be motivated by factors
distinct from the push from climate activists.
The Johan Sverdrup oil field in the North Sea, operated by Equinor, is the third-largest oil field on
the Norwegian continental shelf, with 2.7 billion barrels of oil equivalent. Equinor is planning to cut
the carbon-intensity of energy products it sells by at least 50% as part of the energy transition related
to climate change.
Energy transition has climbed towards the top of the agenda in the boardrooms of the world’s largest
oil and gas companies. With electrification and renewable energy on the rise, Big Oil is striving to
adapt to a transformation that could eventually render their business obsolete if they don’t latch on
to the opportunities it brings. The result could be a massive sell-off of assets as the biggest
petroleum players concentrate their oil and gas production to the countries where oil and gas is
cheapest and easiest to produce.
The transition to renewable energy poses a threat to oil and gas production in the longer term as
solar and wind power is expanding on the energy supply side, while lower-cost electric
vehicles and better battery technology are driving big changes on the global oil demand side. Big

oil companies have strong skills within energy and own assets globally that they can use to remain
competitive as the transition proceeds. Some oil players may also choose to just stick with oil and
gas only, but then they clearly need to be among the best in this game.
Regardless of strategy, the big oil companies need to scale down their global presence in oil and
gas by focusing on countries with growth potential where oil and gas production can deliver
significant cash flow and profit at the lowest possible cost and carbon footprint.
Where $100 billion is up for grabs globally
Our analysis of the geographic spread and need for increased focus for the large listed companies,
also referred to as “Majors+” — U.S.-based ExxonMobil, Chevron and ConocoPhillips, and
European players BP, Shell, Total, Eni and Equinor — concludes that these eight companies
together may want to sell asset worth more than $100 billion to concentrate on their most promising
country holdings.
The oil majors have a long history of going wherever there is money to be made on oil and gas, and
have established presence in almost every corner of the world. However, competition has stiffened
in many countries as national oil companies and governments have taken more control of national
resources and the number of small and medium-sized companies has increased. We see this for
example in Indonesia and Malaysia, with state-owned companies Pertamina and Petronas,
respectively, or in Norway and the United Kingdom, where independents have increased their role
significantly.
This trend has been going on for many years, but now the energy transition is putting even more
pressure on the majors as they see that renewables will also require a growing part of future
investment budgets.
Equinor expects 15-20% of its investments to be directed towards new energy solutions by 2030.
BP total capital expenditures in 2020 are expected to be around $12 billion, with the majority spent

on upstream oil and gas targets, but it plans to increase its investments in low carbon projects to
around $3-4 billion a year by 2025 and $5 billion a year by 2030.
They are well aware of the need to focus their portfolios to improve cash flow, efficiency and
competitiveness as the energy transition accelerates — but the steps they have taken so far may
be too small or too slow.
The wide geographical presence of the Majors+ means that they are also spreading their technical
and management resources out over a large number of countries. We have looked at the size of
the cash flow and growth potential in each country per company, and combined this with how the
country growth potential ranks globally. Based on this we see that the biggest eight publicly listed
oil and gas companies may seek to exit 203 country positions, shedding all the assets held in a
country.
All the companies would keep a presence in the U.S., which has by far the largest growth potential
due to the shale revolution. Canada would also see many companies stay for similar reasons, but
most would exit the carbon-intensive oil sand production.
On the other end of the scale, we expect quite a few countries where only one oil major would be
likely to stay. For example: Argentina (BP), Ghana (Eni) and Guyana (ExxonMobil). In some of these
countries it could be tempting for others to stay or increase their presence as the competition may
be more limited, such as in Guyana, where ExxonMobil has established a very strong position.
The top eight publicly listed oil and gas companies in the world may shed as much as $100 billion
in assets around the world, according to a new analysis from Rystad Energy, but that does not mean
they are walking away from fossil fuels in a hurry.
Rystad Energy
In recent months we have seen that the majors already are putting larger portfolios up for sale.
ExxonMobil has exited Norway and is planning several country exits including the U.K., Romania
and Indonesia, while Royal Dutch Shell tried to exit a key LNG asset in Indonesia in 2019.
This shows that they are well aware of the need to focus their portfolios to improve cash flow,
efficiency and competitiveness as the
energy transition accelerates — but
the steps they have taken so far may
be too small or too slow.
Exiting countries would free up cash
that the majors could use to invest in
renewables, if that is their key growth
strategy, or to pay dividends to their
shareholders, even in challenging
Covid-19 times. If they don’t want to
go down the renewable route, the
capital could be used to strengthen
prioritized country positions by buying
assets from their peers or swapping
assets with other players.
U.S.-based Big Oil is behind
A key reason why some companies are less aggressive on investing in renewables is the strategic
belief that there is a need for oil and gas for a long time, and as long as they are among the best in
oil and gas related to profitability and emissions, they will do well. Another reason could be that with

all the changes going on within the renewable business, they may choose to be a follower rather
than an early mover, who do not always end up as the winners.
We expect many of these majors to sell more of the assets with high-emission intensity to meet
long-term targets for reducing emissions and help finance more investments in renewables. This
gives a double effect if emissions are measured per energy unit being produced. This strategy is
already underway for European majors such as Total, Shell and Equinor, which have committed to
reduce the carbon intensity from the energy products they sell by 50% to 60%. Eni aims to cut
absolute emissions by 80% by 2050 and BP aims to be net zero on an absolute basis across the
carbon in its upstream oil and gas production by 2050.
Compared with their Europe-based peers, the U.S. majors ExxonMobil, Chevron
and ConocoPhillips are communicating lower ambitions on carbon emissions.
For these companies, the outcome of the upcoming U.S. presidential election may have a significant
impact on their strategy, as we expect the policies of a Democratic administration may seek to
reduce greenhouse gas emissions from petroleum production and other sources more rapidly than
those of a continued Republican administration. However, it is not necessarily straightforward for a
new administration to make many changes too quickly in energy politics on the climate side, as they
also may need to consider effects on economics and energy security.
The challenge and opportunity for the Big Oil going forward will be to maneuver with energy
transition speeding up, with a big push for the renewables and reducing emissions, but still also a
large demand for oil and gas, all in a context of changes in the global power balance and effects of
the ongoing Covid-19 epidemic.

NewBase Energy News 06 October 2020 - Issue No. 1379 call on +971504822502, UAE
The Editor:” Khaled Al Awadi” Your partner in Energy Services
NewBase energy news is produced Twice a week and sponsored by Hawk Energy Service – Dubai, UAE.
For additional free subscriptions, please email us.
About: Khaled Malallah Al Awadi, Energy Consultant
MS & BS Mechanical Engineering (HON), USA
Emarat member since 1990
ASME member since 1995
Hawk Energy member 2010
www.linkedin.com/in/khaled-al-awadi-38b995b
Mobile: +971504822502
khdmohd@hawkenergy.net or khdmohd@hotmail.com
Khaled Al Awadi is a UAE National with over 30 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 the UAE operations base. Khaled is the Founder
of NewBase Energy, and an international consultant, advisor, ecopreneur and
journalist with expertise in Gas & Oil pipeline Networks, waste management, waste-
to-energy, renewable energy, environment protection and sustainable development.
His geographical areas of focus include Middle East, Africa and Asia. Khaled has
successfully accomplished a wide range of projects in the areas of Gas & Oil with
extensive works on Gas Pipeline Network Facilities & gas compressor stations.
Executed projects in the designing & constructing of gas pipelines, gas metering &
regulating stations and in the engineering of gas/oil supply routes. Has drafted &
finalized many contracts/agreements in products sale, transportation, operation & maintenance agreements.
Along with many MOUs & JVs for organizations & governments authorities. Currently dealing for biomass
energy, biogas, waste-to-energy, recycling and waste management. He has participated in numerous
conferences and workshops as chairman, session chair, keynote speaker and panelist. Khaled is the Editor-
in-Chief of NewBase Energy News and is a professional environmental writer with more than 1400 popular
articles to his credit. He is proactively engaged in creating mass awareness on renewable energy, waste
management and environmental sustainability in different parts of the world. Khaled has become a reference
for many of the Oil & Gas Conferences and for many Energy program broadcasted internationally, via GCC
leading satellite Channels. Khaled can be reached at any time, see contact details above.
NewBase: For discussion or further details on the news above you may contact us on +971504822502, Dubai, UAE
NewBase 2020 K. Al Awadi

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