New base 30 november 2021 energy news issue 1472 by khaled al awadi

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NewBase Energy News 30 November 2020 No. 1472 Senior Editor Eng. Khaled Al Awadi
NewBase for discussion or further details on the news below you may contact us on +971504822502, Dubai, UAE
Saudi Aramco awards contracts worth $10bn to develop giant
Jafurah gas field
The National Alkesh Sharma + NewBase
Saudi Aramco awarded contracts worth $10 billion for its Jafurah gas field, marking the beginning
of the development of its giant unconventional gas field. The world's largest oil exporting company
has awarded 16 subsurface and engineering, procurement and construction (EPC) contracts, it said
on Monday.
The deals were awarded to domestic and international service companies and involve several
projects on the Jafurah programme. Unconventional resources refer to those that required
advanced extraction methods.
The capital expenditure at Jafurah – the largest non-associated gas field in Saudi Arabia – is
expected to reach $68bn over the first 10 years of development. The government is committed to
the empowerment of national companies such as Aramco and no other energy company in the world
is empowered to the same extent
The development of Jafurah will positively contribute to the kingdom’s energy mix and it has been
made possible thanks to the close co-operation between more than 17 agencies, Prince Abdulaziz
bin Salman Al Saud, Saudi Arabia’s Energy Minister, said.

“The government is committed to the empowerment of national companies such as Aramco, and no
other energy company in the world is empowered to the same extent by the state, or by the Ministry
of Energy which oversees the concession to develop the kingdom’s hydrocarbon resources,” Prince
Abdulaziz said.
With an estimated 200 trillion standard cubic feet of gas in place, the Jafurah basin hosts the largest
liquid-rich shale gas play in the Middle East.
This covers an area of 17,000 square kilometres. The production of natural gas at Jafurah is
expected to increase to 2 billion standard cubic feet per day (scfd) of shale gas by 2030, from 200
million scfd in 2025, with 418 million scfd of ethane and around 630,000 barrels per day of gas
liquids and condensates, which are feedstock for the petrochemical industry.
It will make Saudi Arabia, the Arab world’s largest economy, one of the world’s largest natural gas
producers. The project is a key component of Aramco’s long-term strategy and the company
expects total overall life cycle investment at Jafurah to exceed $100bn.
Aramco expects to create more than 200,000 direct and indirect jobs through its unconventional gas
programme at the Jafurah, North Arabia and South Ghawar fields. This is a pivotal moment in the
commercialisation of Saudi Arabia’s vast unconventional resources programme, Amin Nasser, chief
executive and president of Aramco, said.
“It is a breakthrough that few outside the kingdom thought was possible and which has positive
implications for energy security, economic development and climate protection.
“Gas has a critical role to play in the energy transition and it will help to significantly reduce emissions
in the domestic energy sector, while providing a feedstock for low-carbon hydrogen and ammonia,”
Mr Nasser said.
Jafurah is expected to contribute to Saudi Arabia’s goal of producing half of its electricity from gas
and half from renewables as the kingdom pursues its 2060 net-zero target. At peak production,
Aramco’s unconventional gas programme is expected to replace around half a million barrels of
crude oil a day that would otherwise have been used for domestic consumption.

The Jafurah gas development alone is expected to replace more than 300,000 barrels of crude oil
a day at peak production.
“The development of Jafurah is a game-changer for our unconventional resources programme. It
will be one of the most modern, cost-efficient shale development schemes in the industry and
observe the highest environmental and safety standards,” said Nasir K Al Naimi, Aramco’s upstream
senior vice president.
Aramco, like other major oil producers, has benefited from higher crude prices. Last month, the oil
exporting company said its third-quarter profit more than doubled on higher crude prices and
improved refining margins.
Net profit in the three-month period to the end of September increased to $30.4bn, from $11.8bn in
the same period a year ago, the company said in a regulatory filing to the Tadawul stock exchange,
where its shares are traded.
It unveiled plans to target net-zero carbon emissions by 2050 after the kingdom said it aimed to
neutralise its emissions by 2060.

UAE at 50: Emirates looks to the future as a sustainable
producer of energy
The National - Jennifer Gnana
Opec's third-largest producer has embraced energy transition and positioning itself as a leader in
new fuels such as green and blue hydrogen
Last year, the UAE announced the discovery of 80tcf of shallow gas reserves in an area between
Abu Dhabi and Dubai – the biggest discovery in 15 years. Courtesy Adnoc
The UAE has come a long way from the time the first oil well was struck and crude became the
country's most important commodity, bringing wealth and prosperity to its people. Now, 50 years
on, the country is looking ahead to the next half a century, where hydrocarbons will no longer be
the mainstay of the world economy.
The UAE is innovating along with other regional and global producers to diversify its assets, improve
efficiency, turn to renewables as an alternative source and grow into a world leader in developing
hydrogen.

Oil and gas, however, remain critical to the development of the country, with Abu Dhabi National Oil
Company, the state energy giant, continuing to invest in developing hydrocarbon resources.
The UAE accounts for about 4 per cent of global oil production, with the bulk of the output from
fields owned and managed by Adnoc. The country is also on track to raise its overall capacity of
production to 5 million barrels per day by 2030.
The emirates, which generates power from gas is also substantially increasing the volumes of the
fuel, which is lower carbon to meet its growing consumption requirements.
The UAE, Opec's third-largest producer, consumes around 7.4 billion cubic feet (bcf/d) of gas per
day largely to meet power demand, with the total share of imported fuel at 30 per cent, energy
consultancy FGE estimates.
The UAE announced the discovery of additional reserves of 7 billion “stock tank” barrels of oil, 58
trillion cf of conventional gas and 160tcf of unconventional gas in 2019.
This pushed the country up the rankings in terms of hydrocarbon reserves, data from the US Energy
Information Administration showed. Last year, the UAE also announced the discovery of 80tcf of
shallow gas reserves in an area between Abu Dhabi and Dubai — the biggest discovery in 15 years.
Adnoc has also advanced more efficient production of oil and gas over the past five years, deploying
big data and artificial intelligence to produce hydrocarbons more efficiently.
In February, Adnoc said it generated $1.1 billion in business value through the deployment of Big
Data and analytics at its Thamama Centre, which oversees upstream operations. The company
accrued $2bn in cost savings over the past five years by employing advanced technology and
digitalisation to optimise its drilling operations.

The Thamama centre, which is named after the most dominant reservoir formation in Abu Dhabi, is
part of the company's continuing investments in advanced technology, digitalisation and artificial
intelligence, in order to drive greater efficiencies.
Adnoc has also formed a joint venture known as AIQ with Abu Dhabi artificial intelligence firm Group
42 to develop and commercialise AI products and applications for the oil and gas industry. AIQ,
Group 42 and the world's largest energy services firm, Schlumberger, also have an agreement to
develop and sell AI products for the global exploration and production market.
The UAE also plans to find additional uses for crude to meet the growing global demand for
chemicals, as well as to create a manufacturing hub in the country. The country plans to triple
petrochemical production capacity from 4.5 million tonnes — currently produced entirely by the
Borouge facility in Ruwais — by 2025.
Adnoc is also an early starter among regional energy companies in terms of opening up assets to
foreign investment. Even in the midst of the pandemic, Adnoc helped attract Dh62bn ($16.8bn) in
foreign direct investment to the UAE this year, mainly through various multibillion dollar transactions
signed in the midstream and infrastructure segments.
Between 2016 and 2020, the state-owned firm helped drive Dh237bn in FDI flows to the UAE.
At the height of the pandemic, a consortium of the world’s leading infrastructure and sovereign
wealth funds signed an agreement worth $20.7bn to invest in Abu Dhabi’s natural gas pipelines
infrastructure. The transaction, the largest single global energy infrastructure deal at the time and
the Middle East's biggest, will unlock $10.1bn of foreign investment into the UAE.
Global Infrastructure Partners, Brookfield Asset Management, Singapore’s sovereign wealth fund
GIC, Ontario Teachers’ Pension Plan Board, South Korea's NH Investment & Securities and Italy’s
Snam took stakes in Adnoc’s lucrative midstream assets.

Adnoc also entered into a $5.5bn deal with Apollo Global Management to lease some of its
properties, which led to a further FDI inflow of $2.7bn.
The UAE has continuously tried to position itself ahead of the curve and in many respects is a
bellwether of changing regional market dynamics. It has embraced the energy transition by taking
a leading position in new fuels such as green and blue hydrogen as it looks to tap the growing
market for low-carbon fuel.
Following the latest edition of Abu Dhabi International Petroleum Exhibition and Conference, by The
National's estimate, the week-long event resulted in more than $13.7bn of investment pledged to
develop the UAE's upstream and downstream sectors. The figure takes into account only planned
investments and awards by Adnoc, and does not include preliminary agreements by other
companies.
The UAE in line with the global efforts to transition away from fossil fuels will also now host the 28th
Conference of Parties in 2023 following its pledge this year to reach net zero by the middle of the
century.
The country created history by becoming the first Arab nation to pledge to offset all carbon emissions
it creates domestically ahead of Cop26. As the country looks forward to a new age away from oil,
Adnoc is also adding renewables to its portfolio. Along with Taqa, a major player in utilities, Adnoc
will form a joint venture to invest in renewables.
The companies joined forces to create a global renewable energy and green hydrogen venture that
will have a generating capacity of 30 gigawatts by 2030. The two companies will partner on domestic
and international renewable energy and waste-to-energy projects, as well as the production,
processing, and storage of green hydrogen.

Morocco: Sound Energy signs gas sales agreement for Phase 2
Tendrara development … Source: Sound Energy
Sound Energy, the Moroccan focused upstream gas company, has entered into a binding gas sale
and purchase agreement (the 'GSA') in respect of the Phase 2 development of the Tendrara
Production Concession with Morocco's state-owned power Company ONEE (Office National de
l'Electricite et de l'Eau potable) for the sale of natural gas from the Tendrara Concession in Eastern
Morocco over a 10 year period.
The Company has entered into the GSA, which is in addition to the conditional Phase 1 micro
liquified natural gas TE-5 Horst development related gas sales agreement entered into by the
Company with Afriquia Gaz and announced by the Company on 29 July 2021, alongside its state-
owned Tendrara Production Concession partner ONHYM (Office National des Hydrocarbures et
des Mines and together with the Group the 'Tendrara JV Partners').

Under the GSA, the Tendrara JV Partners have conditionally committed to producing, processing
and delivering gas from the Tendrara Production Concession, in accordance with required ONEE
gas specifications, to the Gas Maghreb-Europe pipeline connecting Algeria to Spain and crossing
Morocco (the 'GME Pipeline'), for an annual contractual volume up to 350 million cubic meters of
natural gas per year for a period of 10 years, with an annual take or pay volume of 300 million cubic
meters.
The GSA includes a fixed unitary price for the annual volume of 0.3 bcm per annum (approx. 29.0
MMscf/d or a minimum amount of energy of approx. 10.5 million MMbtu per annum to be delivered
at the point of sale), which will result in annual gross revenues attributable to the Tendrara
concession (100%) as envisaged in the original binding memorandum of understanding between
the parties announced by the Company on 30 October 2019
The GSA is conditional upon, inter alia: (i) all necessary authorisations and permits having been
granted for the construction of the Phase 2 gas installations (ii) the final investment decision, when
taken, by the Tendrara JV Partners, being approved by the Moroccan Ministries of Transition Energy
and Sustainable Development and Economy and Finance; and (iii) the entry by the Tendrara JV
Partners of an interconnection agreement with the operator of the GME Pipeline, and the
commencement of works, for the connection of the Tendrara Production Concession to the GME
Pipeline. The conditions to the GSA are required to be satisfied within 90 days of signature, however
an extension is allowable with the consent of all parties.
Graham Lyon, Sound Energy's Executive Chairman, commented:
'The agreement of the GSA is an important and long-awaited step which will allow the Company to
progress development planning for the proposed TE-5 Horst Phase 2 development. It also
underpins the ongoing discussions with potential and identified funding partners. These potential
partners have expressed strong interest in participation in the proposed regional infrastructure and
asset development via vendor financing, equity participation and alternate lending solutions, in order
to build the long-term domestic infrastructure and gas supply in and for Morocco. Satisfying the
conditions precedent within a tight 90-day timetable is challenging, however all parties have
expressed support to conclude with financiers.
We are delighted with this confirmation that the UK-Morocco, ONHYM and Sound Energy
partnership is working well, and such a business partnership can enhance, with the strong support
of our shareholders and our local partners, the expected 5.7% economic growth of the Kingdom of
Morocco despite the COVID-19 pandemic.'

UK: CNOOC Ltd commences production at Buzzard Phase II
Development … source CNOOC
CNOOC Limited has announced that the Buzzard Phase II development, offshore UK North
Sea has safely commenced production.
Buzzard Phase II is located approx. 100 kms northeast of Aberdeen, United Kingdom with average
water depth of approx. 96 meters. While fully utilizing the existing Buzzard facility, the project has
also built a set of underwater production systems. 2 production wells and 2 water injection wells
have been brought on stream. Buzzard Phase II is expected to reach its peak production of
approximately 12,000 barrels of oil equivalent per day in 2022, increasing Buzzard’s production to
80,000 BOEPD in total.
Buzzard Phase II Development commences production (Source: CNOOC Ltd)
Mr. Xia Qinglong, President of CNOOC Limited said:
'We are very pleased with the commencement of production at Buzzard Phase II. Constant
development of the field will strongly promote the growth of the Company's overseas production in
the future.'
CNOOC Petroleum Europe Limited, a wholly owned subsidiary of CNOOC Limited, is the operator
of Buzzard and has 43.21% interest. The remaining interests are held by Suncor
Energy (29.89%), Harbour Energy (21.73%) and ONE-Dyas (5.16%).

Europ Energy Prices Jump as Colder Weather to Boost Demand
Bloomberg
Energy prices in Europe surged on Monday after weather forecasts showed colder temperatures
for the next two weeks that will lift demand for heating.
Benchmark Dutch natural gas for next month climbed as much as 9.7%, German month-ahead
power surged 11% and carbon futures jumped to a record. Widespread below-average
temperatures are seen through most of Europe for the next two weeks with the lowest levels
expected in the Nordic region, according to Maxar Technologies LLC.
As winter approaches, energy markets are set to get increasingly sensitive to the prospect
consumption will increase amid lower temperatures in the northern hemisphere.
European gas prices have been under pressure since demand recovered during the summer and
new supplies have dried up, with more liquefied natural gas diverting to Asia and Russia focusing
on filling up its own storage sites.
“Given how tight the gas balance looks presently, any significant period of cold below the seasonal
average would likely push forecasts for end-of-season gas inventories toward critical levels, driving
prices higher,” said Stefan Ulrich, a gas analyst at BloombergNEF. “If the winter turned out to be

particular cold, we could not rule out further extraordinary measures to calm the gas and by
extension power markets.”
A bitterly cold blast, that moved in from the Arctic at the weekend and was still being felt on Monday,
is expected to ease throughout the week. The chill is pushing up short-term power prices in
Germany and France to near-record levels. Carbon for December delivery jumped to a record 75.74
euros ($85.439) on ICE Endex.
The weather is going to get colder in Russia with temperatures dipping to lower than minus 15
degrees Celsius (59 degrees Fahrenheit) in the west by the middle of next week. That’s where some
of the nation’s biggest consumers are located and the freezing weather may boost local demand.
The fundamentals for carbon are bullish, according to Redshaw Advisors Ltd. The key downside is
the risk of further lockdowns being rolled out to prevent the spread of coronavirus which would
impact industrial demand for emissions permits.
Benchmark Dutch gas for next month climbed as high as 96.25 euros a megawatt-hour on ICE
Endex in Amsterdam. A series of outages in Norway are set to curb supplies.
Gas production at the Sleipner field in Norway was cut on Sunday because of corrective
maintenance until Tuesday, according to network operator Gassco AS. Production at Visund,
another field in Norway, will be halted on Wednesday for yearly maintenance.
On top of that, gas storage sites in Europe are depleting quickly. Stores are 64% full, way below the
10 years average of 86% for this time of the year.

US Recent legislation reduce the U.S. Strategic Petroleum Reserve
Source: U.S. Energy Information Administration, Petroleum Supply Monthly and Congressional legislation
On Tuesday, November 23, the White House announced plans to make 50 million barrels of crude
oil available to the market through a combination of exchanges and accelerating previously
announced sales.
With these sales and several other legislated drawdowns, SPR inventories could decline from 618
million barrels (as of October 1, 2021) to about 314 million barrels by the start of the 2032 fiscal
year, the lowest level since March 1983.
The Infrastructure Investment and Jobs Act, passed earlier this month, includes a provision to draw
down 87.6 million barrels of crude oil from the U.S. Strategic Petroleum Reserve (SPR) in fiscal
years (FY) 2028 through 2031.
The SPR was established in the 1970s to alleviate the effects of unexpected oil supply reductions.
The reserve was designed to hold up to 714 million barrels of crude oil across four storage sites
along the Gulf of Mexico, where much of the U.S. petroleum refining capacity is located.
Crude oil can be released from the SPR under four conditions: emergency drawdowns, test sales,
exchange agreements, and nonemergency sales. Emergency drawdowns and test sales are
relatively rare.
The most recent emergency drawdown occurred in 2011 in response to production disruptions in
Libya, and the most recent test sale occurred in 2014. The SPR has released crude oil
under exchange agreements 12 times since 1996, most recently after Hurricane Harvey in 2017.
In these exchange agreements, crude oil is released to private companies and repaid in kind by
specified dates with additional barrels, similar to monetary interest on a loan.

Congress has also authorized nonemergency sales of SPR crude oil to respond to lesser supply
disruptions or to raise revenue for the U.S. Treasury.
For example, the Fixing America’s Surface Transportation Act, passed in 2015, and The Bipartisan
Budget Act of 2018 collectively call for the sale of more than 160 million barrels of crude oil from the
SPR in FYs 2022 through 2027.
One of the SPR’s core missions is to hold enough oil stocks to fulfill U.S. obligations under the
International Energy Program, the 1974 treaty that established the International Energy Agency
(IEA).
As a member of the IEA, the United States is obligated to maintain stocks of crude oil and petroleum
products, both public and private, to provide at least 90 days of U.S. net import protection. The U.S.
Department of Energy calculates this value by dividing the SPR inventory level by EIA’s sum for net
crude oil and petroleum product imports.
As net imports of crude oil and petroleum products into the United States declined in recent years,
the volume needed to meet the 90-day import coverage also fell.
Note: IEA is the International Energy Agency. Days of cover increase as net imports decrease or
switch to net exports. Only months with less than 360 days of cover are shown. On a monthly basis,
days of cover have exceeded 360 days 18 times since 2018, and the United States was a net
exporter in 17 months.
In October 2019, the United States exported more crude oil and petroleum products than it imported,
becoming a net exporter for the first time in EIA data, which dates back to 1977. IEA members who
are net petroleum exporters do not have stockholding obligations.
Although the United States has occasionally imported more petroleum than it exported in some
months since late 2019, SPR inventory levels have continued to provide sufficient coverage for net
import protection.

NewBase November 30-2021 Khaled Al Awadi
NewBase for discussion or further details on the news below you may contact us on +971504822502, Dubai, UAE
Oil bound for gains as OPEC+ guards supply, but virus threat looms
Reuters + NewBase
Oil prices will stay elevated into next year as OPEC+ keeps a tight leash on supply despite U.S.-led
strategic crude releases, a Reuters poll showed on Tuesday, but a COVID-19 resurgence fuelled
by the Omicron variant could loom large over the outlook.
A survey of 39 economists and analysts - kicked off before Omicron grabbed headlines-- forecast
Brent crude to average $71.25 a barrel in 2021, up from the $70.89 consensus in October and the
$70.57 average this year. The 2022 Brent outlook was raised to $75.33 from $74.04.
This is the highest projection this year for the benchmark.
Oil price special
coverage

"We expect that OPEC+ will remain cautious in adding barrels, but does not want oil prices to move
past $80 for any sustained period of time," said John Paisie, president of Stratas Advisors. "OPEC+
is also still worried about shale producers in the U.S. ramping up production in response to higher
prices."
U.S. crude was forecast to average $68.52 and $73.31 a barrel in 2021 and 2022 respectively,
versus October's $68.62 and $71.21 consensus.
Oil forecasts
Demand was seen growing by 4.5-6.0 million barrels per day (bpd) in 2021 and by 3.3-5.0 million
bpd next year, led by Asia. Oil prices have retreated from recent highs as concerns over Omicron
coupled with the release of stockpiles by the United States and other nations posed headwinds.
The Organization of the Petroleum Exporting Countries and allies, a group known as OPEC+, will
meet this week to assess the Omicron variant's impact and decide whether to adjust its plan to
increase output by 400,000 barrels per day in January and beyond.
A few analysts noted that while OPEC+ could rein in a ramp-up in output in response to the stockpile
releases, rising coronavirus cases and potential U.S. shale growth could also impact prices next
year.
Morgan Stanley on Monday cut its first quarter 2022 Brent crude price forecast to $82.50 per barrel
from $95, stating that the Omicron variant creates a downside risk to its demand forecast.

NewBase Special Coverage
The Energy world –Nov - 30- -2021
Climate Tech Investments Can Add Up to Net Zero
By Clara Ferreira Marques
Reaching the world’s climate targets will mean expanding the use of cutting-edge technologies that
already exist. Making them more accessible requires cash — and generous government support
Vast sums are now pointed in the direction of reaching net-zero emissions by 2050. That’s good
news: We require somewhere between $100 to $150 trillion in climate investment over the next
three decades, and ignoring global warming would prove a costly and potentially irreversible
cataclysm.
In fact, the crucial coming years need to see sums going into the energy system to more
than double from the current $1.7 trillion a year. But does the promised cash add up to what the
planet needs? Not quite.
There’s the inconvenient fact that the cash isn’t reaching every corner of the globe in sufficient
quantities. Too much stays in the developed world: That’s a problem, given developing economies
will account for nearly 70% of global power demand by 2050. In 2020, 90% of energy transition
funding went to high- and upper-middle income economies, according to BloombergNEF.
There’s also, less obviously, a technology problem. Yes, more funding is going into renewable
energy sources, electric vehicles and the like — and that’s vital, given the scale at which those
sources and the infrastructure supporting them need to expand and develop. More is needed.
Yet a significant proportion of emissions abatement will have to come from elsewhere, often using
applications that deal with harder-to-tackle industrial corners of the economy. Then there’s green
food production and the need to rethink energy efficiency.

Many of these technologies already exist, but remain too small and too expensive to be put to
widespread use — say, direct air capture, which extracts carbon straight from the atmosphere; or
green hydrogen, which produces the versatile energy carrier by using renewable energy to split
water; or, indeed, modular nuclear power plants, green steel and alternative fuels for aviation or
shipping.
In time, costs for successful technologies do come down, as seen with the drop in the cost of wind
and solar energy. In the decade to the start of this year, the unsubsidized cost of utility-scale
solar has fallen 90% since 2009 and wind is down more than 70%, according to investment bank
Lazard Ltd.
That’s transformational — even if supply chain woes have lately reversed some of that price decline.
But the drop owed something to time, a luxury the world doesn’t have, and much to government
support. Can that effect be repeated, faster?
Take carbon removal. In the likelihood that we overshoot the global carbon budget, technologies
that could help us remove billions of tons of carbon from the atmosphere, as well as from
smokestacks, and store it, may well prove crucial. Direct air capture is up and running — but at
a tiny scale. The landmark Orca direct-air capture facility, which opened in September in
Iceland, will capture 4,000 tons of CO2 a year, making it the largest in the world. That makes up for
the annual emissions of about 250 U.S. residents.

The cost is also exorbitant: individuals can pay up to $1,200 per metric ton of CO2 while the cost
for bulk purchases is closer to $600. Carbon is currently trading close to record levels on the
European market at over 70 euros, or roughly $80.
Research suggests that a price below $100 is not only potentially desirable but achievable — the
U.S. government’s “Earthshot” initiative is targeting carbon removal and storage at $100 — but that
requires far more capital to come into the business, not just a handful of firms and individuals
wanting to offset their emissions.
Governments have to step in and create demand to help attract the industrial players who will scale
it up.
This pre-commercial and emerging territory is usually the domain of venture capital, and early-stage
funding for climate- and clean-technology startups from private equity, accelerators, angel investors
and the like surged to a record in the first nine months of this year, reaching just under $37 billion,
according to BNEF.
Much of that, though, is going into improving existing areas: funding for battery companies and
electric-vehicle companies has soared. More importantly, venture capital cannot solve this problem
alone. Attracting industrial players to riskier tech that has immediate applications and green benefits
may matter more to final development and use.
So what needs to happen? Education and risk reduction, for one. Larger investors, who don’t play
at the cutting edge, will not invest in what they don’t understand and haven’t experienced.
Philanthropic capital and multilateral banks, too, can help lower risk and open up investments to a
wider pool of potential backers.
The real game-changer, though, is government support, with clear policy direction and, crucially, by
creating demand. That can succeed especially when building on existing strengths, as Europe is
doing with green hydrogen.
NewBase Energy News 05 November 2021 - Issue No. 1468 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.
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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. Has Mechanical Engineering BSc. & MSc. Degrees from leading U.S.
Universities. 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 news articles issues, 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
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