New base 24 october 2019 energy news issue 1288 by khaled al awadi (1)

Copyright © 2019 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 24 October 2019 - Issue No. 1288 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: Dubai to harness RO technology to increase water
production by 305 MIGD by 2030: DEWA CEO
WAM/ /Tariq alfaham
By 2030, Dubai will use Reverse Osmosis, RO, to expand the production capacity of desalinated
water by 305 million imperial gallons per day, MIGD, thus increasing the total capacity of desalinated
water production to 750 MIGD, compared to the current 470 MIGD, said Saeed Mohammed Al
Tayer, MD & CEO of the Dubai Electricity and Water Authority, DEWA.
Al Tayer made this remark during his opening address at the International Desalination Association,
IDA, Leaders' Summit on the second day of the IDA World Congress.
The event was hosted under the theme, ''Crossroads to Sustainability'', and will run until 24th
October, 2019, at the Dubai International Convention and Exhibition Centre.
''The DEWA conducted a study to improve water production and analysed the economic and
technical feasibility of adopting seawater RO technology to produce water using cheap and clean
energy in our planned water production expansion. The DEWA adopts a clear strategy to ensure
that by 2030, the total energy required to meet the demand for Dubai's desalinated water will be
www.linkedin.com/in/khaled-al-awadi-38b995b

generated 100 percent from clean energy sources using a mix of clean energy and waste heat. This
will allow Dubai to exceed global targets for using clean energy to desalinate water,'' he added.
The summit brought together prominent leaders from the water and energy sectors, who discussed
critical long-term sustainable solutions within the desalination and water reuse industry.
"To support the vision of our wise leadership, DEWA has world-class infrastructure, with a capacity
of 11,400MW of electricity and 470 MIGD of desalinated water to meet the growing demand in
Dubai. We are currently desalinating water through the Combined Cycle Co-Generation, which is
efficient and depends on using waste heat created by the production of electricity for water
desalination," Al Tayer said.
The summit also witnessed a panel discussion titled, "The Industrial Water–Energy Nexus: Are we
on the Right Path?" and "Innovation in the Advanced Water Treatment Market".
It also included sessions under the title "Expanding the Public-Private Partnership Model to New
and Existing Markets", "Trends in the EPC Market: Is Competing on Cost vs Quality Sustainable?"
and "Bankability of Mega Water Projects: How to Increase the Appetite of Lenders and Financial
Development Institutions?"

Saudi Acwa Power to finalise funding on $11.5bn Saudi
gasification scheme by the end of 2019 … The National
Acwa Power will reach financial close on an $11.5 billion gasification project being developed with
Saudi Aramco and Air Products by the close of the year, according to its chief executive. The utility
company is building the project with Saudi Aramco and Air Products
The utilities company based in Riyadh will have a 25 per cent stake in the scheme, which is
expected to produce steam, hydrogen, oxygen and a small amount of desalinated water, all for local
consumption and use at the nearby Jazan refinery.
“Power generation capacity [on the scheme] is essentially 3,800 megawatts. We expect to bring
that to a close this year. It’s $11.5bn and it’s been integrated with other components,” Paddy
Padmanathan told The National.
State-owned Aramco is building a 23 billion riyal (Dh22.5bn) refinery in Jazan Economic City on the
Red Sea coast, which is part of the kingdom’s plans to develop industrial zones, create jobs and
attract foreign direct investment. US company Air Products will hold at least a 55 per cent stake in
the joint venture.
Acwa Power, in which Saudi Arabia’s sovereign Public Investment Fund has a 40 per cent stake, is
one of the kingdom’s leading developers in conventional and renewables. Saudi Arabia, which has
been moving away from burning crude to gas-fired power plants, is now looking at green energy as
it seeks to free up its oil for export.

The kingdom recently revised its renewable energy targets to 27.3 gigawatts from 9.5GW, to be
achieved by 2024. Acwa Power, which is constructing the kingdom’s first utility-scale solar power
project, a 300MW scheme in Sakaka, is bidding on $5bn worth of projects for the remainder of the
year.
“But more interestingly, we have about
$6bn of projects that we have bid,
which are under evaluation and I
would say 90 per cent of the projects
that we are bidding on are in the
renewables space or in the
desalinated water space,” said Rajit
Nanda, the company’s chief
investment officer.
In August, Saudi Arabia invited 60
pre-qualified companies to submit
bids for six solar energy projects, for
which it hopes to attract $1.4bn in
investment.
Bidding on the schemes has not
started yet, said Mr
Padmanathan. The kingdom’s
Renewable Energy Project
Development Office is likely to tender
the projects in two batches from
January 6, he added. Acwa Power will
participate in the utility scale tenders
which have a total capacity of
1,410MW.
“It’s a structured bid in two groups. They’re both solar, together it is about just under 3,000MW,”
said Mr Padmanathan.
In the UAE, Acwa Power submitted the lowest bid of 1.69 US cents for the 900MW fifth phase of
the Sheikh Mohammed bin Rashid Solar Park this month. The developer, Dubai Electricity and
Water Authority, is evaluating the shortlisted bidders and is expected to sign a power purchase
agreement with the chosen party in the “early part of 2020”, said Mr Nanda.
Last week, Acwa Power also signed a preliminary agreement with Aramco to invest up to $3bn in a
gas-to-power scheme in Bangladesh. The 3,600MW project will be built in “three phases with each
phase being 1,200MW”, said Mr Nanda.
“The intention is to sign the PPA in the second half of 2020 and to achieve financial close and start
construction in 2021 for phase one and thereafter we will build each of the second and third phases
in the space of 12 months,” he said.
Aramco will supply liquefied natural gas for the project with Bangladesh expected to import 3 to 4
million tonnes of the super-chilled fuel on an annual basis through state-owned Petrobangla.
Acwa Power's planned initial public offering meanwhile would be done "sooner than later," said Mr
Padmanathan, with a domestic listing being the priority.

Oman PDO award Petrofac flare gas recovery contract
Oman Observer +NewBase
UK-based international oilfield and petrochemical engineering services giant Petrofac has announced
that it has secured a contract to support the development of a flared gas recovery project in the
Sultanate. It was one of three engineering contracts awarded to the company by clients in the Sultanate,
as well as Libya.
“In Oman, Petrofac will support Flare to Value LLC (F2V) by producing a basic engineering package to
recover gas that is currently flared at three onshore locations. Petrofac’s focus will be on the fast-track
execution of constructible, operable and standardised solutions that maximise modularisation and
minimise interruptions to ongoing operations,” said Petrofac.
Flared gas recovery and conversion to energy is a major initiative in the Sultanate driven by a desire to
capture waste gas volumes that are typically before they are flared with the goal of generating electricity
to power nearby oilfield operations.
Petroleum Development Oman (PDO) is at the forefront of this initiative, as are a number of operators
who are also motivated by a desire to reduce harmful gas emissions and resulting impacts to the
environment.
Nick Shorten, Managing Director, Petrofac Engineering and Production Services West, said: “We are
delighted to have secured these engineering contracts to support clients in our core markets in the
Middle East and North Africa. These awards demonstrate how our high-end consultancy and front-end
engineering expertise can support our clients in unlocking complex projects.”
About our flare gas recovery
Traditionally, flare gas recovery is done with re-compression, for example, either for enhanced oil
recovery or by re-injecting into the main process. This adds cost but does not add income directly.

We believe that it is possible to use a lean and mean process train to turn flare gas into profitable
products rather than waste.
Depending on the location and available infrastructure, the valuable product can be electricity, LPG,
or pipeline-quality natural gas (in order of increasing profitability). In the absence of a nearby gas
grid pipeline, production of CNG, LNG, or synthetic crude oil, methanol or dimethylether (via a GTL
process) may be more suitable.
Added value
 Monetize your waste stream while reducing your CO2 footprint
 Built for your unique business needs and operating conditions
 Skid-mounted units that easily integrate into your
production system
 Low energy demands with optimized heat
integration technology and low emission systems
 Robust and reliable units designed with lean
engineering methods

Kuwait Petroleum leads global new-build LNG regasification
capacity additions by 2023 … Posted in Oil & Gas, GlobalData - Press Release
Kuwait Petroleum Corp is expected to account for 8% capacity share in the global liquefied natural
gas (LNG) regasification industry from new-build (planned and announced) projects between 2019
and 2023, according to GlobalData, a leading data and analytics company.
The company’s report, ‘H2 2019 Global Capacity and Capital Expenditure Outlook for LNG
Regasification Terminals – India Continues to Dominate Global Regasification Capacity Additions
and Capex Spending’, reveals that Kuwait Petroleum Corp has the highest LNG regasification
capacity additions globally among companies with 1.2 trillion cubic feet (tcf) by 2023.
Adithya Rekha, Oil and Gas Analyst at GlobalData, explains: “The entire regasification capacity
additions of Kuwait Petroleum Corp comes from the proposed Al-Zour LNG regasification terminal
in Kuwait. This planned offshore terminal is expected to start operations in 2020 with a capacity of 1.2
tcf.”

After Kuwait Petroleum, Hiranandani Group is the second highest company globally in terms of
regasification capacity additions by 2023. The company is expected to add 717 billion cubic feet
(bcf) of regasification capacity through five terminals by 2023. Of this total capacity, 449 bcf is
expected to come from three planned projects while 268 bcf comes from two early-stage announced
projects.
Rekha concludes: “Mitsubishi Corp closely follows Hiranandani Group with the third highest global
regasification capacity additions of 709 bcf through three planned and announced regasification
terminals by 2023.”
About KIPIC
Kuwait Integrated Petroleum Industries Company (KIPIC) inspires a core belief, to “Make More
Possible”. We nurture a culture of operational excellence, corporate responsibility and commitment
to Health Safety and Environment through a highly transparent process.
The LNGI project is the first of its kind in the State of Kuwait and has been established to meet
Kuwait's growing needs for cleanest fuel (natural gas) to generate electricity, as well as the needs
of other nat ural gas consumers such as oil refineries and petrochemical industries.
Project Features
 The LNGI project is the world’s largest capacity LNG storage & regasification green field
project.
 LNGI project is the first permanent LNG Import terminal in Kuwait.
 The area of each LNGI tank (being 6,644 m²) is 1.04 times of Jaber Al-Ahmad Stadium’s
Pitch (6,400 m²).
 The usage of 8 LNG Tanks, 9% Nickel Plate, is approximately 18,390 ton, which is equivalent
to 13,130 Toyota Camry (2017).

U.S. exports crude oil to more destinations than it imports from
Source: U.S. Energy Information Administration, Petroleum Supply Monthly
As U.S. crude oil export volumes have increased to an average of 2.8 million barrels per day (b/d)
in the first seven months of 2019, the number of destinations (which includes countries, territories,
autonomous regions, and other administrative regions) that receive U.S. exports has also increased.
Earlier this year, the number of U.S. crude oil export destinations surpassed the number of sources
of U.S. crude oil imports that EIA tracks.
In 2009, the United States imported crude oil from as many as of 37 sources per month. In the first
seven months of 2019, the largest
number of sources in any month
fell to 27. As the number of
sources fell, the number of
destinations for U.S. crude oil
exports rose. In the first seven
months of 2019, the United States
exported crude oil to as many as
31 destinations per month.
This rise in U.S. export
destinations coincides with the
late 2015 lifting of restrictions on
exporting domestic crude oil.
Before the restrictions were lifted,
U.S. crude oil exports almost
exclusively went to Canada.
Between January 2016 (the first

full month of unrestricted U.S. crude oil exports) and July 2019, U.S. crude oil production increased
by 2.6 million b/d, and export volumes increased by 2.2 million b/d.
Source: U.S. Energy Information Administration, Petroleum Supply Monthly
The United States has also been importing crude oil from fewer of these sources largely because
of the increase in domestic crude oil production. Most of this increase has been relatively light-sweet
crude oil, but most U.S. refineries are configured to process medium- to heavy-sour crude oil. U.S.
refineries have accommodated this increase in production by displacing imports of light and medium
crude oils from countries other than Canada and by increasing refinery utilization rates.
Conversely, the United States has exported crude
oil to more destinations because of growing
demand for light-sweet crude oil abroad. Several
infrastructure changes have allowed the United
States to export this crude oil. New, expanded, or
reversed pipelines have been delivering crude oil
from production centers to export terminals. Export
terminals have been expanded to accommodate
greater crude oil tanker traffic, larger crude oil
tankers, and larger cargo sizes.
More stringent national and international
regulations limiting the sulfur content of
transportation fuels are also affecting demand for
light-sweet crude oil. Many of the less complex refineries outside of the United States cannot
process and remove sulfur from heavy-sour crude oils and are better suited to process light-sweet
crude oil into transportation fuels with lower sulfur content.
The U.S. Energy Information Administration’s monthly export data for crude oil and petroleum
products come from the U.S. Census Bureau. For export values, Census trade data records the
destinations of trade volumes, which may not be the ultimate destinations of the shipments.

Venezuela: Chevron to drill for oil in for three more months
Reuters + NewBase
The U.S. Treasury Department on Monday renewed a license allowing Chevron, the last U.S.
operating energy company in Venezuela, to continue drilling in the country for another three months
through Jan. 22.
The license has been a subject of intense debate within the Trump administration as it pursues a
campaign to oust socialist President Nicolas Maduro. Its renewal represented a win by some in the
administration, such as Secretary of State Mike Pompeo, who see keeping a U.S. company in
Venezuela as an asset that could lead to a speedy recovery after any ouster of Maduro.
Other Trump administration officials believe allowing Chevron to stay results in oil output that helps
keep Maduro in power by allowing him to pay down debts. Several administration officials favor
allowing the license to expire even after Trump’s hawkish former national security adviser John
Bolton, who had been an opponent of the license, stepped down last month.
Chevron executives “remain focused on our base business operations and supporting the more
than 8,800 people who work with us and their families,” said spokesman Ray Fohr. The company
is reviewing terms of the latest license.
The renewal effectively adds no new restrictions, according to a review of past licenses.
Chevron (CVX.N) has been in Venezuela for nearly 100 years and has about 300 direct employees
there. Its joint ventures with state oil company PDVSA support about 8,800 people. The ventures
produce the equivalent of about 200,000 barrels per day of oil, and Chevron’s stake in them recently
averaged about 34,000 bpd, the company said.

In January, the United States imposed sanctions on Venezuela’s state-run oil company PDVSA in
an effort to oust Maduro. But it issued Chevron a six-month license to operate, which has now been
renewed for two three-month periods.
Crude oil output in the OPEC nation has dropped from well over 2 million bpd in 2014 to just over 1
million bpd by the end of 2018, the result of lower prices and what critics say is years of
underinvestment and mismanagement. Blackouts and U.S. sanctions have accelerated the
collapse: The country now produces just 600,000 bpd.
The Treasury Department said the license does not authorize transactions related to shipments of
diluents, which Venezuela needs to thin its heavy oil for processing.
The license also covers oil field service companies Halliburton Co (HAL.N), Schlumberger (SLB.N),
GE’s Baker Hughes (BHGE.N) and Weatherford International. All have largely halted operations in
Venezuela because of the instability.
“President Donald Trump’s 2020 re-election bid could make future extensions increasingly difficult,”
said Kevin Book, an analyst at ClearView Energy Partners. “The White House may see a strong
stand against Maduro as a way to appeal to Latino voters.

Egypt:Dragon Oil to invest $1 billion in Gulf of Suez after buying BP stake
Reuters + NewBase
Dubai-based Dragon Oil Ltd said on Monday it had completed the purchase of BP’s oil concessions
in Egypt’s Gulf of Suez and will invest $1 billion over five years to boost and extend their production.
Dragon, owned by Emirates National Oil Company (ENOC), said it had replaced BP as the partner
of state-owned Egyptian General Petroleum Corporation (EGPC) in the Gulf of Suez Petroleum
Company (GUPCO), which has 11 offshore oil exploration and production concessions.
GUPCO’s target had been to increase the
concessions’ combined production to 75,000
barrels per day (bpd) of oil by 2021 from the
current 60,000 bpd. But Dragon said it plans
to boost production to above 75,000 bpd and
maintain this level for 10 years by further
drilling and investing $1 billion over the next
five years. The deal between Dragon Oil and
BP was announced in June, pending
approval by Egypt’s ministry of petroleum.
The company announced on Monday its
plans to invest $1bn over five years to
boost and extend their production.
Under the terms and conditions of the
purchase, Dragon Oil became the
partner of the Egyptian General
Petroleum Corporation (EGPC) instead
of BP in all oil production and discovery
concessions in the Gulf of Suez, where
the Gulf of Suez Petroleum Company
(GUPCO) operates on behalf of the
EGPC and the contractor.
The completion of the purchase will enhance the strategic production of the company
and its investments in a number of regions and countries of the world such as
Turkmenistan, Iraq, and Afghanistan, bringing the daily production of the company
estimated at 150,000 barrels per day, as this production is part of the strategy of Dragon
Oil to reach the production of 300,000 barrels equivalent per day by 2026.
Dragon Oil plans to boost production to levels above 75,000 barrels per day (bpd) by
increasing drilling activity.
This important deal for Dragon Oil follows the recent successes of investment in the
Egyptian petroleum sector, which had a positive impact in attracting international
companies to invest in the Egyptian petroleum sector and was the main motive for
entering into this deal.
Egypt is considered attractive for investment, and Egypt and the UAE have friendly
relations.

NewBase October 24 – 2019 Khaled Al Awadi
NewBase For discussion or further details on the news below you may contact us on +971504822502 , Dubai , UAE
Oil slips on profit-taking, weak demand outlook
Reuters + NewBase
Oil prices dipped on Thursday after sharp gains in the previous session following a surprise draw in
U.S. crude inventories, with concerns over a weak demand outlook adding to downward pressure.
Brent crude futures LCOc1 fell 33 cents, or 0.5%, to $60.90 a barrel by 06.11 GMT. The international
benchmark crude rose 2.5% on Wednesday to settle at $61.17 a barrel, levels not seen since Sept. 30.
West Texas Intermediate (WTI) crude futures CLc1 dropped 40 cents, or 0.71%, to $55.57 per
barrel. U.S. crude closed 3.3% higher in the previous session.
“Oil is seeing profit-taking in Asia after last night’s sharp up-move,” said Jeffrey Halley, senior market
analyst at OANDA.
U.S. crude inventories fell 1.7 million barrels in the week ended Oct. 18, compared with analysts’
expectations for a 2.2 million barrel build, data from the Energy Information Administration showed.
Oil price special
coverage

This was in stark contrast with earlier inventory data released by industry group the American
Petroleum Institute (API), which showed a build of 4.5 million barrels in U.S. crude stocks. The EIA
said the drawdown in weekly stocks came as refineries hiked crude runs and oil imports fell, which
prodded a jump in both benchmark crude grades on Wednesday.
But persistent concerns about weak demand outlook continue to weigh on market sentiment, traders
said.
“Flagging global economic growth and rising downside risks have kept global risk appetites
measured as traders deliberate weaker fuel demand for the coming term,” said Benjamin Lu, analyst
at Singapore-based brokerage Phillip Futures.
Some market participants said a decline in U.S. product inventories, as shown by the EIA data,
could point to underlying demand.
“The EIA report may be an indication that oil demand is not as bad as a current dreary run of global
headline macro data might suggest,” said Stephen Innes, market strategist at AxiTrader. The
prospects of deeper production cuts by the Organization of the Petroleum Exporting Countries
(OPEC) and its allies also helped to support the market.
Russian Energy Minister Alexander Novak, however, said on Wednesday that no formal calls have
been made yet to change the current global oil supply deal.
OPEC, Russia and other producers have since January implemented a deal to cut oil output by 1.2
million barrels per day (bpd) until March 2020 to support the market. The producers will meet to
review the policy on Dec. 5-6.

NewBase Special Coverage
News Agencies News Release Oct. 24-2019
Renewables 2019 - Distributed solar PV
Market analysis and forecast from 2019 to 2024
The installation of solar PV systems on homes, commercial buildings and industrial facilities is set
to take off over the next five years, transforming the way electricity is generated and consumed,
according to the International Energy Agency’s latest renewable energy market forecast.
The report forecasts that the world’s total renewable-based power capacity will grow by 50%
between 2019 and 2024. This increase of 1,200 gigawatts – equivalent to the current total power
capacity of the United States – is driven by cost reductions and concerted government policy efforts.
Solar PV accounts for 60% of the rise. The share of renewables in global power generation is set
to rise from 26% today to 30% in 2024.
Forecast overview
Globally, distributed solar PV capacity is forecast to increase by over 250% during the forecast
period, reaching 530 GW by 2024 in the main case. Compared with the previous six-year period,
expansion more than doubles, with the share of distributed applications in total solar PV capacity
growth increasing from 36% to 45%.
Commercial and industrial systems remain the largest growth segment because they are usually
more inexpensive and have a relatively stable load profile during the day that can enable larger
savings on electricity bills, depending on the policy scheme in place.
Of all renewable technologies, additional growth potential is highest for distributed PV because

consumer adoption can be very rapid once the economics become attractive. Distributed PV growth
could therefore be almost 30% higher in the accelerated case, assuming:
1) faster investment cost reductions, especially in countries where BoS costs remain high;
2) clarification of regulatory and incentive schemes in multiple markets, especially concerning
remuneration and the length of self-consumption accounting periods;
3) the reduction of non-economic barriers such as protracted application processing, high
connection fees and unjustified deployment caps;
4) access to affordable financing, especially in emerging economies;
5) speedy implementation of retail market reforms, enabling more cost-reflective electricity
pricing for residential and commercial users.
Distributed PV remuneration schemes
Renewables 2019 categorises distributed solar PV remuneration schemes into five main categories:
1) buy-all, sell-all; 2) net metering; 3) real-time self-consumption at the wholesale price; 4) real-time
self-consumption at a value-based price (usually between the wholesale and retail price), whereby
utilities or regulators estimate the value of PV generation based on avoided generation capacity
expansions, fuel expenditures and any additional costs, and on benefits to the system or society
(grid integration costs, CO2 reduction value, capacity credits, etc.); and 5) real-time self-
consumption at zero remuneration.
Distributed PV remuneration for forecast growth, 2019-24
Note: In buy-all, sell-all schemes, all PV generation is remunerated with a fixed tariff that can be higher or
lower than the retail rate. No rem. = no remuneration of excess genera
The use of these schemes to increase distributed PV deployment varies by segment
and region. Over 80% of residential growth during 2019 24 will be from buy-all, sell-all
schemes or net metering, mainly in the United States and China. Conversely, the main

driver for commercial growth is self-consumption in real time, largely because of the
good match between electricity demand and peak PV production at midday.
Value-based tariffs cover 30% of distributed PV growth up to 2024, especially driven by
commercial systems in Europe and residential systems in Australia. Most US states,
some countries in Europe, and relatively nascent markets such as Latin America and
the Caribbean, India and Association of Southeast Asian Nations (ASEAN) economies
are still implementing net-metering schemes that remunerate excess generation with
retail tariffs.
Residential solar PV forecast
Residential solar PV capacity expands from 58 GW in 2018 to 143 GW in 2024, and annual capacity
additions are expected to more than triple to over 20 GW by 2024. China’s residential PV growth is
forecast to accelerate substantially compared with the previous six years. As a result, the country
registers the largest installed residential solar PV capacity in the world by 2024 thanks to FITs under
the buy-all, sell all model, surpassing the European Union, the United States and Japan.
The United States is the second-largest growth market after China, with expansion driven by
federal tax incentives and annual net-metering schemes in many states (Figure 2.15). In addition,
California’s new mandate requiring PV panels on new homes and buildings of up to three storeys
after 2020 contributes to growth.
Australia and Japan lead Asia Pacific deployment, while growth continues to be limited in India and
other emerging and developing countries due to minimal policy incentives, the absence of
regulations (or their inadequate implementation), and low, cross-subsidised residential electricity
tariffs, making the economics unattractive. In Latin America, residential expansion is expected to
accelerate because of new net-metering and self-consumption policies in Brazil, Chile and
Argentina.
Commercial industrial solar PV forecast

Commercial and industrial solar PV capacity is forecast to expand from 150 GW in 2018 to 377 GW
in 2024, with annual capacity additions increasing by 50% to 44 GW in 2024. China remains the
largest growth market, but unlike for the residential segment, expansion in the Asia Pacific region
is larger than in Europe and North America, mainly owing to strong policy incentives in Japan, Korea
and India.
In the European Union, commercial PV growth in the main case forecast accelerates compared with
the previous six-year period, thanks not only to sustained deployment in Germany but also to
emerging growth markets such as France, the Netherlands and Spain as a result of improved policy
environments.
Distributed PV accounts for almost half of the growth in the overall solar PV market through 2024.
Contrary to conventional wisdom, commercial and industrial applications rather than residential
uses dominate distributed PV growth, accounting for three-quarters of new installations over the
next five years. This is because economies of scale combined with better alignment of PV supply
and electricity demand enable more self-consumption and bigger savings on electricity bills in the
commercial and industrial sectors.
“Distributed PV’s potential is breathtaking, but its development needs to be well managed to
balance the different interests of PV system owners, other consumers and energy and distribution
companies,” Dr Birol said. “The IEA is ready to advise governments on what is needed to take full
advantage of this rapidly emerging technology without jeopardising electricity security.”
According to the report’s Accelerated Case, improving economics, policy support and more
effective regulation could push distributed PV’s global installed capacity above 600 GW by 2024,
almost double Japan’s total power capacity today. Yet this accelerated growth is still only 6% of
distributed PV’s technical potential based on total available rooftop area.
As in previous years, Renewables 2019 also offers forecasts for all sources of renewable energy.
Renewable heat is set to expand by one-fifth between 2019 and 2024, driven by China, the
European Union, India and the United States. The heat and power sectors become increasingly
interconnected as renewable electricity used for heat rises by more than 40%. But overall,
renewable heat potential remains vastly underexploited. The share of renewables in total heat
demand is forecast to remain below 12% in 2024, calling for more ambitious targets and stronger
policy support.

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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For additional free subscription emails please contact Hawk
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Khaled Malallah Al Awadi,
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MS & BS Mechanical Engineering (HON), USA
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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 of experience in
the Oil & Gas sector. Currently working as Technical Affairs Specialist for
Emirates General Petroleum Corp. “Emarat“ with external voluntary Energy
consultation for the GCC area via Hawk Energy Service as a UAE operations
base , Most of the experience were spent as the Gas Operations Manager in
Emarat , responsible for Emarat Gas Pipeline Network Facility & gas
compressor stations . Through the years, he has developed great experiences
in the designing & constructing of gas pipelines, gas metering & regulating
stations and in the engineering of supply routes. Many years were spent
drafting, & compiling gas transportation, operation & maintenance agreements along with many
MOUs for the local authorities. He has become a reference for many of the Oil & Gas Conferences
held in the UAE and Energy program broadcasted internationally, via GCC leading satellite
Channels.
NewBase : For discussion or further details on the news above you may contact us on +971504822502 , Dubai , UAE
NewBase 2019 K. Al Awadi

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