New base 30 january 2020 energy news issue 1312 by khaled al awadi

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NewBase Energy News 30 January 2020 - Issue No. 1312 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:World Association of Nuclear Operators confirms
Barakah Unit 1 readiness for start up
WAM/Rasha Abubaker + NewBase
The Emirates Nuclear Energy Corporation, ENEC, and its subsidiary Nawah Energy Company,
Nawah, announced today that an extensive operational readiness assessment performed by an
international team of nuclear industry experts from the Atlanta Centre of the World Association of
Nuclear Operators, WANO, has concluded that Unit 1 of the Barakah Nuclear Energy Plant in Abu
Dhabi is ready to start up.
The WANO Pre-start Up
Review, PSUR, is a globally-
recognised nuclear industry
assessment which is conducted
in line with the international
industry standards set by
WANO, of which ENEC and
Nawah are both members.
During the PSUR process,
which took place in November
2019, WANO teams reviewed
and examined numerous
functional and cross-functional
areas that are essential for the
safe start-up and operation of
the Unit, ranging from operator performance and operations and maintenance, through to work
management and emergency preparedness. The final results of the PSUR were recently
communicated by WANO Atlanta Center representatives, which confirmed that Unit 1 of the
Barakah plant is ready to start up.
The WANO PSUR comes after a series of assessments carried out by several national and
international regulatory organizations during the past years. International collaboration with
nuclear organizations is a central commitment of the 2008 Policy of the UAE on the Evaluation
and Potential Development of Peaceful Nuclear Energy. The policy set the objective to "engage
WANO and its members to provide assessments and shared experience feedback" as an
essential component of its commitments to complete operational transparency, as well as the
continuous pursuit of the highest standards of safety and security.
"The fact that our first Unit and our team of experts successfully completed this international start
up assessment by WANO is a major milestone for the UAE Peaceful Nuclear Energy
Programme," said Mohamed Al Hammadi, ENEC CEO.
www.linkedin.com/in/khaled-al-awadi-38b995b

"It provides international recognition that our plant, people and processes meet international start
up standards and that the Barakah plant fully aligns to the commitments made in 2008 by the
Nation of complete operational transparency, and the pursuit of the highest standards of safety,
quality and security. We take this achievement with great responsibility while we continue to
support Nawah in obtaining regulatory approval from FANR to safely and gradually commence
producing clean, safe and reliable electricity to power the growth of the UAE for the next 60
years."
The PSUR is the culmination of over 30 support missions and peer reviews by WANO, and
reflects Nawah’s strong Culture of Safety and commitment to upholding the highest international
standards of safety, security, quality, and transparency.
It also demonstrates the success of Nawah’s ongoing operational readiness activities as it
prepares to load the first nuclear fuel assemblies into Unit 1, which is expected to take place in Q1
2020, once all requirements have been met and Nawah is in receipt of the Operating License from
the Federal Authority for Nuclear Regulation, FANR, the UAE’s independent nuclear regulator.
Mark Reddemann, Chief Executive Officer of Nawah Energy Company, said, "Successfully
completing WANO’s PSUR of Unit 1 of the Barakah Nuclear Energy Plant is a testament to our
commitment to the highest national and international regulations and standards. As we progress
towards the secure and safety-led start-up of Unit 1, we will continue to work closely with our
partners to ensure we demonstrate our readiness to receive the Operating License from the
Federal Authority for Nuclear Regulation, as we work to pursue the highest standards of
operational excellence."
Nawah is concluding the final requirements to demonstrate operational readiness in preparation to
receive the Operating License from FANR, prior to commencing the loading of the first fuel
assemblies safely into Unit 1 of the Barakah plant, scheduled for Q1 2020. Once the fuel
assemblies are loaded into the reactor, Nawah will begin the start-up sequence for Power
Ascension Testing, where operators will safely raise power generation levels over a number of
months, prior to commercial operation.

UAE: Sharjah new gas discovery will boost the emirate's drive
toward self-sufficiency … The National + NewBase
Sharjah's new discovery of natural gas and condensate - it's biggest in more than three decades
is a game changer in some respects for the emirate. The Mahani well, which was drilled by state-
owned Sharjah National Oil Company (Snoc) and Italian major Eni, has tested gas at flow rates of
50 million standard cubic feet per day and has also found condensate - valuable liquid that fetches
a high price in the markets. Here's why the new discovery is significant for the emirate's
economy.
Power needs
Sharjah requires more power generation capabilities to keep up with demand from a growing
population that is set to reach almost two million by 2020, making it the second-most populous
emirate. The emirate is home to more than 1.4 million people. The emirate is actively looking at
various options to diversify its power mix to meet the rising demand of a growing population and
easing pressures on the existing supply of electricity.
Self-sufficiency
The emirate's utility has embarked on a plan to achieve self-sufficiency in power generation by
2021, by boosting domestic capacity as well as looking to privatise parts of its business. As part of
the overhaul, the Sharjah Electricity and Water Authority plans to add 1.5 gigawatts of capacity to
the grid to offset the 700MW to 1.2GW of power being imported from the national grid by 2021.
Gas shortages
Snoc supplies the gas to the Sharjah state utility, with the state oil company earlier planning to
deploy a floating storage and regasification unit moored offshore at the Hamriya Port to plug the
shortage of gas in the emirate. However, the plans are now in the backburner following the launch
of an upstream licensing round and the successful award of three concessions to Eni. Sharjah's

plan to look for new gas finds in 2018 came amid an increasing uptick in upstream activity across
the UAE, with Abu Dhabi National Oil Company as well as Ras Al Khaimah also launching bidding
rounds focused on gas to increase domestic production of the clean fuel. For Sharjah, it was
particularly important as the emirate also buys gas via the Dolphin Pipeline, from which it has
looked to diversify. Snoc also plans to launch more licensing rounds as it looks to plug its gas
deficit.
Potential
Eni which is active across the Middle East including offshore exploration in the Eastern
Mediterranean, has bought into Sharjah's potential. With the first well, Mahani, now tested to have
a flow rate of 50 million cubic feet per day, the European energy firm has the potential to
commercialise its find.
"That's a very good rate and they should be able to sustain it in a commercial flow rate. So far
promising and encouraging for them and they have more wells to drill," said Robin Mills, chief
executive at Qamar Energy.
"Most will go to the power sector which is the biggest consumer in Sharjah, perhaps some will go
to industry as well," he added.
The discovery “has the potential to boost local energy supplies and economic development,” said
Majid Jafar, chief executive of Crescent Petroleum. “Sharjah has the largest number of industrial
companies in the UAE, and is the gas hub for the Northern Emirates.”

Morocco/Egypt: SDX Energy provides update on drilling
operations in Morocco and Egypt… Source: SDX Energy
SDX Energy has announced that the OYF-2 well in Morocco (SDX 75% working interest) has
been drilled to a measured depth of 1,210 meters and has encountered commercial quantities of
gas in excess of pre-drill estimates. The discovery also confirms that the Company's core
productive area extends to the north.
Both the Upper and Lower Guebbas targets in OYF-2 were encountered and reservoir thickness
and quality were better than pre-drill expectations. The Upper Guebbas was encountered at a
measured depth of 1,001 meters, while the Lower Guebbas was penetrated at a measured depth
of 1,120 meters.
Management estimates that approximately 1.3 to 1.9 bcf1 of gas is recoverable from the horizons
encountered by the OYF-2 well, which will be tested in February. The discovery will be tied into
the Company's infrastructure when required, at an estimated cost of approximately US$2 million
net to SDX. Furthermore, the discovery has de-risked a further 0.5 to 1.0 bcf of Prospective
Resources in the western compartment of the Lower Guebbas target which the Company expects
to recover with a single development well in the future.
The rig has now moved to the BMK-1 location, which is approximately 11 kilometres to the north
of OYF-2. BMK-1 will again test the extent of the northern expansion of the Company's core
productive area and, if successful, could de-risk a number of similar close-by prospects. After
BMK-1, one more close to infrastructure well and two other potentially play-opening wells in Lalla
Mimouna will be drilled to complete the campaign in March.

Egypt
South Disouq (SDX Working Interest 55%)
Preparations continue at South Disouq for two exploration wells targeting gross unrisked P50
volumes of up to 104 bcf from the same horizons encountered in the Company's four discoveries
to date. The first well, Salah, which is expected to spud in mid/late February and complete in April
2020, is targeting a gross unrisked P50 prospect of 71 bcfe (Company estimate)1.
The second well, Sobhi, which is expected to spud in late April/early May and complete in early
June, is targeting a gross unrisked P50 prospect of 33 bcfe (Company estimate) 1. If successful,
these two wells would require short, 8.0 km and 5.8 km, tie-ins to the South Disouq Central
Processing Facility with SDX's share of the tie-in cost estimated at US$2.5 million and US$1.9
million respectively.
West Gharib (SDX Working Interest 50%)
In early February the Company is planning to spud an appraisal/development well in the Rabul
area of its West Gharib concession. If successful, this well could add approx. gross 200-300 bbl/d
of production.
Mark Reid, CEO of SDX, commented:
'We have a particularly busy year ahead with the drill bit, giving us the opportunity to increase
significantly the Company's reserves life. OYF-2 in Morocco is a very positive start, a discovery
which is larger than pre drill expectations, and confirmation that our core productive area extends
to the north. With the planned follow on development well, we now have the potential to increase
our total reserves in Morocco to approximately three to four years of customer demand with our
gas being sold under five and ten year fixed priced contracts at an average gas price of circa
US$11/mcf.

Egypt in two Mediterranean deals with Exxon Mobil: ministry
Reuters + NewBase
The deals involve a minimum investment of $332 million, the ministry said in a statement. Exxon
Mobil announced the acquisition of more than 1.7 million acres last month.
The first agreement is for exploration in the North East Amriya block, with a minimum investment
of $220 million, the ministry said.
The second is for the North Marakia block, with a minimum investment of $112 million.
The discovery of the giant Mediterranean field of Zohr by Italy’s Eni in 2015 sparked increasing
interest and investment in Egypt’s energy sector.
The country is trying to position itself as an energy hub in the eastern Mediterranean, importing
gas from Israel and exporting to Jordan and potentially to Europe and Asia.
The ministry said the Exxon Mobil agreements bring the total number of deals with investors to 82
since 2014, with a total minimum investment of about $16 billion for the drilling of 340 wells.

U.S.:EIA expects U.S. net natural gas exports to double by 2021
Source: U.S. Energy Information Administration, Natural Gas Monthly and Short-Term Energy Outlook
In its Short-Term Energy Outlook (STEO), released on January 14, the U.S. Energy Information
Administration (EIA) forecasts that U.S. natural gas exports will exceed natural gas imports by an
average 7.3 billion cubic feet per day (Bcf/d) in 2020 (2.0 Bcf/d higher than in 2019) and 8.9 Bcf/d
in 2021.
Growth in U.S. net exports is led primarily by increases in liquefied natural gas (LNG) exports and
pipeline exports to Mexico. Net natural gas exports more than doubled in 2019, compared with
2018, and EIA expects that they will almost double again by 2021 from 2019 levels.
The United States trades natural gas by pipeline with Canada and Mexico and as LNG with
dozens of countries. Historically, the United States has imported more natural gas than it exports
by pipeline from Canada. In contrast, the United States has been a net exporter of natural gas by
pipeline to Mexico. The United States has been a net exporter of LNG since 2016 and delivers
LNG to more than 30 countries.
In 2019, growth in demand for U.S. natural gas exports exceeded growth in natural gas
consumption in the U.S. electric power sector. Natural gas deliveries to U.S. LNG export facilities
and by pipeline to Mexico accounted for 12% of dry natural gas production in 2019. EIA forecasts
these deliveries to account for an increasingly larger share through 2021 as new LNG facilities are
placed in service and new pipelines in Mexico that connect to U.S. export pipelines begin
operations.
Net U.S. natural gas imports from Canada have steadily declined in the past four years as new
supplies from Appalachia into the Midwestern states have displaced some pipeline imports from
Canada. U.S. pipeline exports to Canada have increased since 2018 when the NEXUS

pipeline and Phase 2 of the Rover pipeline entered service. Overall, EIA projects the United
States will remain a net natural gas importer from Canada through 2050.
U.S. pipeline exports to Mexico increased following expansions of cross-border pipeline capacity,
averaging 5.1 Bcf/d from January through October 2019, 0.5 Bcf/d more than the 2018 annual
average, according to EIA’s Natural Gas Monthly.
The increase in exports was primarily the result of increased flows on the newly
commissioned Sur de Texas–Tuxpan pipeline in Mexico, which transports natural gas from Texas
to the southern Mexican state of Veracruz. Several new pipelines in Mexico that were scheduled
to come online in 2019 were delayed are expected to enter service in 2020:
 Pipelines in Central and Southwest Mexico (1.2 Bcf/d La Laguna–Aguascalientes and 0.9
Bcf/d Villa de Reyes–Aguascalientes–Guadalajara)
 Pipelines in Western Mexico (0.5 Bcf/d Samalayuca–Sásabe)
U.S. LNG exports averaged 5 Bcf/d in 2019, 2 Bcf/d more than in 2018, as a result of several new
facilities that placed their first trains in service. This year, several new liquefaction units (referred
to as trains) are scheduled to be placed in service:
 Trains 2 and 3 at Cameron LNG in Louisiana
 Train 3 at Freeport LNG in Texas
 Trains 5–10, six Moveable Modular Liquefaction System (MMLS) units, at Elba Island in
Georgia
In 2021, the third train at the Corpus Christi facility in Texas is scheduled to come online, bringing
the total U.S. liquefaction capacity to 10.2 Bcf/d (baseload) and 10.8 Bcf/d (peak). EIA expects
LNG exports to continue to grow and average 6.5 Bcf/d in 2020 and 7.7 Bcf/d in 2021, as facilities
gradually ramp up to full production.
20

U.S. crude oil production growing through 2021, but slowly
Source: U.S. Energy Information Administration, Short-Term Energy Outlook, January 2020
In the January 2020 update of its Short-Term Energy Outlook (STEO), the U.S. Energy
Information Administration (EIA) forecasts that U.S. crude oil production will average 13.3 million
barrels per day (b/d) in 2020, a 9% increase from 2019 production levels, and 13.7 million b/d in
2021, a 3% increase from 2020.
EIA’s U.S. crude oil production forecast is based on the West Texas Intermediate (WTI) price
forecast in the January 2020 STEO, which rises from an average of $57 per barrel (b) in 2019 to
an average of $59/b in 2020 and $62/b in 2021. The price forecast is highly uncertain
Crude oil production in the Lower 48 states has a relatively short investment and production cycle.
Changes in Lower 48 crude oil production typically follow changes in crude oil prices and rig
counts with about a four- to six-month lag. Because EIA forecasts WTI prices will decline during
the first half of 2020 but begin increasing in the second half of the year and into 2021, EIA
forecasts U.S. crude oil production will grow slowly until the end of 2020.
Crude oil production in Alaska and the Federal Offshore Gulf of Mexico—which collectively
accounted for about 19% of U.S. total crude oil production in 2019—is driven by long-term
investment that is typically less sensitive to short-term price movements.
Once final data are available, EIA expects the data will show that Lower 48 crude oil production
reached its largest annual average volume of 9.9 million b/d, and EIA expects it to increase further
by an average of 1.0 million b/d in 2020 and 0.4 million b/d in 2021.
EIA forecasts that production from the Federal Offshore Gulf of Mexico will grow by 0.1 million b/d
in 2020 to 2.0 million b/d and to remain relatively flat in 2021 because several projects expected to
come online in 2021 will not start producing until late in the year and will be offset by declines from
other producing fields. Alaska’s crude oil production will remain relatively unchanged at about 0.5
million b/d in both 2020 and 2021.
EIA forecasts that Permian crude oil production will average 5.2 million b/d in 2020, an increase of
0.8 million b/d from 2019 production levels. For 2021, the Permian region will produce an average
of 5.6 million b/d. EIA forecasts that the Bakken region in North Dakota will be the second-largest
growth area in 2020 and 2021, growing by about 0.1 million b/d in each year.

NewBase January 30-2020 Khaled Al Awadi
NewBase For discussion or further details on the news below you may contact us on +971504822502 , Dubai , UAE
Oil price special
coverage

EIA sees crude oil prices will fall in the first half of 2020, then rise through 2021
Source: U.S. Energy Information Administration, Short-Term Energy Outlook, January 2020
In the U.S. Energy Information Administration’s (EIA) January Short-Term Energy
Outlook (STEO), EIA forecasts that the Brent crude oil spot price will average $65 per barrel (b) in
2020 and $68/b in 2021 and that the West Texas Intermediate (WTI) spot price will average $59/b
in 2020 and $62/b in 2021.
EIA expects that crude oil prices will remain elevated in the first few months of 2020, reflecting a
price premium on crude oil from recent geopolitical events. However, this price premium will
diminish in the first half of 2020, and market fundamentals will drive the crude oil price forecast in
the second half of 2020 and in 2021.
Several geopolitical events have provided upward pressure on crude oil prices in recent months.
These events include attacks on oil tankers transiting the Persian Gulf and the Red Sea, the
September 2019 attack on Saudi Arabia’s energy infrastructure, and recent tensions between the
United States and Iran. Monthly average Brent prices rose from $63/b in September to $67/b in
December. Crude oil prices increased during this period despite global liquid fuels inventories
growing by 130,000 barrels per day (b/d).
Further increasing the geopolitical risk premium on global oil prices, the U.S. military action in Iraq
in January 2020 increased uncertainty about potential disruptions to oil production and shipping in
the Middle East. Following these developments, the price of Brent crude oil reached $70/b, but
prices have subsequently fallen.
As the risk premium decreases, EIA assumes that Brent prices will decline in early 2020 to an
average of $62/b in May. EIA does not forecast supply disruptions, and any physical supply
disruptions would put upward pressure on prices.

NewBase Special Coverage
The Energy world – Special Jan-30-2020
Biggest Wind Farms to Get EU Support in Push for Green Power
Bloomberg - Ewa Krukowska and Reed Landberg
Developers for some of the world’s biggest wind farms are poised to get a boost from
the European Union under a new strategy aimed at ensuring the industry makes a larger
contribution to low-carbon power supplies.
Energy Commissioner Kadri Simson said officials in Brussels are working on a package of
measures that will help stimulate the offshore wind industry. It’s part of the Green Deal package, a
far-reaching plan to eliminate greenhouse gas emissions by the middle of the century.
The program would help unlock the potential for wind farms sited in water, where more reliable
breezes make the technology an increasingly cheap way to generate clean electricity. While
politicians like turbines sited far from the eye of voters who object to wind farms on land, the
industry has been hobbled by bureaucratic hurdles and competition for deals, which makes each
project less profitable to build.
“We will have a strategy for offshore wind so that joint projects for big parks can be finalized,”
Simson said in an interview in Brussels on Tuesday. “From our side it means the solutions how we
can support investments into grids, because offshore wind parks will be built in the regions where
we don’t have any grid connections yet.”
Monumental Turbines
The biggest offshore wind turbines are as tall as skyscrapers
Sources: U.S. Department of Energy, Vestas, GE, Bloomberg research

In the coming months, the energy and environment departments of the European Commission,
the EU regulatory arm, will jointly work to draft the strategy. It will focus on the maritime aspects
such as how the wind farms can co-exist with shipping and fisheries. It will also look at spatial
planning and financing for grid expansions needed to support the projects.
The effort would go some way to remove issues holding up developments. Competition between
utilities such as Orsted A/S, Vattenfall AB and EnBW AG to build offshore wind farms has
produced projects so cheap that they work without subsidy, raising questions whether the
companies will make money from them.
The industry also is waiting for governments to put into law goals they have set for expanding
offshore wind power, which would give some assurance about investments planned to give the
industry scale and reduce costs further.
“Political risks are now larger than market snares,” said Stefan Thimm, managing director of
Gemany’s BWO offshore industry lobby, in a Jan. 23 interview. “We need to hedge against that
risk and that questions whether zero bids are going to be repeated anytime soon.”
Europe wants to lead the global fight against climate change and attract investors in clean
technologies under the Green Deal. Commissioner Simson acknowledged that may require tighter
targets for renewable energy for 2030. The current goal is to get 32% of energy from renewables
by the end of this decade.
Windy World
Installed capacity of offshore wind will boom in Europe and China
Source: International Energy Agency

One key point of the strategy for offshore would “consider how different member states will fulfill
their energy targets by cooperating on one site where the grid connection goes to a certain spot in
the mainland,” Simson said.
Offshore wind is a focus because of its enormous potential to generate clean electricity. The
International Energy Agency estimates the industry is growing 2.2% a year and will draw in $840
billion over the next two decades -- but that pace must double to reach climate targets.
Falling Short
Offshore wind needs to grow faster to address climate change, pollution and global energy access
Source: International Energy Agency
BloombergNEF estimates new installations worldwide rose to 7.7 gigawatts last year, up from less
than 2 gigawatts at the start of the decade. It expects about 9 gigawatts of additions in each of the
next five years, growing to an annual pace of 19 gigawatts by the end of the decade, with new
markets emerging in Spain, Italy, Greece and Lithuania.
Hydrogen’s Future Brightens
Hydrogen also will get a boost from the commission’s Green Deal. Simson said she saw the fuel
as interesting solution to decarbonize the sectors where a shift to electricity is not an option.
Those include steel, cement and chemicals, where the industrial process requires heat of more
than 1,000 degrees Celsius.
“It is a solution for how to phase out fossil fuels,” Simson said. “Right now we need to support pilot
projects, which are not yet market-compatible. We have certain funds, for example the Innovation
Fund, which can help industrial sites that are testing such innovative solutions. It might also be a
possible solution for storage. It will definitely play a role in our sector integration strategy.”

Growing LNG Imports to Secure Supplies
Liquefied natural gas also is a focus for the commissioner. She said that “most probably” the
volume of LNG used in Europe will rise as a way to ensure energy security.
“LNG played a very significant role for our energy security aspect. In the past years it was one of
the priorities to secure different routes. We had to have diverse providers of gas. A good network
of LNG terminals has provided us a diversified gas market. We have a certain capacity of LNG
terminals. There’s a lot of projects in the pipeline: in Poland, in Croatia, in Greece, and in
Germany.”
“We are using right now 70% of the capacities that we do have already, and the capacities are
growing. The U.S. is now providing 16% of our LNG and as such it is the third-biggest source of
imports. The share of U.S. LNG has grown rapidly, even if we are comparing numbers from the
last three months these are several times higher than a year ago. So the reason must be that the
price has come down and it’s competitive.”
Monitoring Work in Nord Stream 2 Pipeline
The commission is monitoring how member states apply a revised gas market law to the Nord
Stream 2 pipeline.
The still-unfinished natural gas project will bring Russian flows to Germany through a route under
the Baltic Sea. U.S. sanctions have halted work for now. Another key issue is how the project is
treated under a new EU law, which require the owner and shipper of gas to be different legal
entities.
Nord Stream 2 asked German authorities for an exemption from the EU pipeline rules, arguing it
was eligible for the derogation because the project was completed by May 23, 2019. Germany has
until May 24 to decide how to interpret the project’s completion. “Every member state has the right
to decide what their energy mix is.” Simson said. “We have to monitor that all respective state
agencies apply the law. We are monitoring this process and there are certain criteria that the
German agency has to consider.”

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 sponsored by Hawk Energy Service –
Dubai, UAE.
For additional free subscription emails please contact Hawk Energy
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 a total of 28 years ofexperience 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 broadcastedinternationally, via GCC leading
satellite Channels.
NewBase :For discussion or further details on the news above you may contact us on +971504822502 , Dubai , UAE
NewBase Jan 2020 K. Al Awadi

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