NewBase 11 January 2024 Energy News issue - 1689 by Khaled Al Awadi_compressed.pdf

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NewBase Energy News 11 January 2024 No. 1689 Senior Editor Eng. Khaled Al Awadi
NewBase for discussion or further details on the news below you may contact us on +971504822502, Dubai, UAE
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UAE’s ADNOC makes strategic investment `10.1% in Storegga,
ADNOC + NewBase
ADNOC has taken a 10.1% equity stake in Storegga to become a lead investor in the UK-based
company that focuses on the development of global carbon capture and storage (CCS) projects.
ww.linkedin.com/in/khaled-al-awadi-80201019/
• ADNOC takes 10.1% equity stake in UK-based Storegga which focuses on
the development of global carbon capture and storage projects
• Strategic transaction represents ADNOC’s first international equity
investment in carbon management platform
• Deal with Storegga supports ADNOC’s strategy to leverage carbon
management partnerships and technology to accelerate decarbonization

The strategic transaction represents ADNOC’s first international equity investment in carbon
management and supports the company’s strategy to leverage carbon management partnerships
and technology to advance global carbon capture and storage projects that can accelerate
decarbonization. The investment is enabled by ADNOC’s initial allocation of $15 billion (AED55
billion) to low-carbon solutions and decarbonization technologies.
ADNOC is targeting a carbon capture capacity of 10 million tonnes per annum (mtpa) by 2030,
equivalent to taking over 2 million internal combustion vehicles off the road.
Musabbeh Al Kaabi, ADNOC Executive Director for Low Carbon Solutions and International Growth,
said: 'This strategic investment marks an important milestone in ADNOC’s decarbonization journey
and highlights our commitment to work with partners across industries to deliver practical solutions
to enable a net zero energy future. Carbon capture is an important tool to responsibly reduce carbon
emissions and meet global climate goals and ADNOC will continue to scale-up this technology as
we work towards net zero by 2045.'
ADNOC’s carbon management strategy aligns with the Intergovernmental Panel on Climate
Change’s (IPCC) view that carbon capture and storage is a critical enabler for the world to achieve
net zero by mid-century.
Nick Cooper, CEO, Storegga, said, 'Strategic collaborations are crucial for a pragmatic, prompt and
affordable transition to a low-carbon future. Storegga is therefore ready to stand alongside
traditional energy suppliers to accelerate decarbonization by deploying cost-effective CCS globally.
'Over the past three years we have transformed from a single-project developer in Scotland to an
international force driving global decarbonization efforts. We are excited to now see ADNOC join
our shareholder group. Storegga is fortunate to be backed by investors with the necessary vision
and ambition for the rapid deployment of CCS and carbon removal technologies that are imperative
for meeting the global net zero objectives.'
Storegga has a portfolio of carbon capture projects in the UK, US and Norway. In the UK, Storegga
is leading the development of the Acorn CCS project, which is poised to store up to 10 million tonnes
of CO2 per annum by 2030. The company was recently awarded a license, with partners, to develop
the Trudavang CCS project in Norway and is developing a number of CCS opportunities in the
United States, the most advanced of which is the Harvest Bend CCS project in Louisiana.
ADNOC operates Al Reyadah, the world’s first commercial scale operation to capture and store
CO2 from the steel industry, with a capacity of 800,000 tonnes of CO2 per year. Recently, ADNOC
announced major carbon capture projects, taking its committed investment for carbon capture
capacity to almost 4 mtpa. ADNOC is also one of 50 founding signatories of the Oil and Gas
Decarbonization Charter (OGDC). Launched during COP28 in Dubai, the OGDC is a global
commitment to speed up climate action across the industry.
Storegga completes funding round and welcomes a new shareholder
Storegga, a leading international, independent developer of decarbonisation projects, has closed
its fourth round of funding. It has received further investment from existing shareholders,
including GIC and Macquarie, and welcomes new investment from ADNOC - a diversified energy
group that is advancing lower-carbon solutions by investing in new energies and decarbonisation
technologies.
Storegga has a growing portfolio of decarbonisation projects and has the financial backing to deliver
these as one of the world’s leading independent decarbonisation project developers. Through the

development and delivery of carbon capture and storage (‘CCS’) and hydrogen projects, Storegga
is advancing industrial decarbonisation in sectors such as manufacturing, power generation,
distilling, chemicals and others..
Storegga has a portfolio of CCS projects located in the United Kingdom, the United States, and the
recently announced Trudvang CO2 storage project in Norway. Storegga is also leading the
development of the Acorn Transportation and Storage (T&S) system in Scotland, which is poised to
store up to 10 million tonnes of CO2 per year by 2030. In the UK, Storegga’s Cromarty Hydrogen
Project was recently awarded a contract as part of the UK Government’s first Electrolytic Hydrogen
Business Model allocation round.
The funds raised will be used for delivery of ongoing projects and business development activities
across the company.
Nick Cooper, CEO, Storegga, commented:
'Over the past three years Storegga has transformed from a single-project developer in Scotland
into an international force driving global decarbonisation efforts.
'We are really pleased to add ADNOC to our shareholder group. Already operating the Al Reyadah
CCS project, ADNOC brings sector expertise plus the financial capacity and ambition to play a major
role in the global deployment of CCS and hydrogen. We are also grateful for the reaffirmed support
of our existing shareholders which enable Storegga to continue to progress large-scale
decarbonisation projects and to foster meaningful partnerships with government, communities and
industry to pursue net zero.
'Carbon removal technologies are a foundation for reducing emissions from hard to abate sectors
with high carbon footprints. This funding round will enable further progress across our portfolio
including the Acorn CCS and Cromarty Hydrogen projects in the UK, Trudvang CCS in Norway and
Harvest Bend CCS in Louisiana.'

UAE’s Alpha Dhabi sell stake in Gordon-U.S to Adnoc Drilling JV
The National - John Benny + NewBase
Alpha Dhabi Holding, a unit of Abu Dhabi's International Holding Company, has transferred its 25
per cent stake in US-based oil engineering company Gordon Technologies to a joint venture
with Adnoc Drilling.
This marks the first strategic investment by Alpha Dhabi in the JV, which aims to invest up to $1.5
billion to acquire technology-enabled companies in the oilfield services sector. Alpha Dhabi’s stake
in Gordon Technologies has been valued at about $180 million, the companies said on Tuesday.
The formation of the JV in November along
with the investment in Gordon
Technologies is expected to bring “value
accretive” returns to both shareholders,
while supporting Adnoc Drilling’s long-term
dividend growth profile.
“Through the incorporation of our joint
venture we are set to accelerate
investment in tech-enabled energy
solutions,” said Abdulrahman Al Seiari,
chief executive of Adnoc Drilling.
“Access to these technologies will …
accelerate well delivery optimisation in the
development of unconventional resources as we strive to enable gas self-sufficiency for the nation.”
Founded in 2014, Gordon provides measurement-while-drilling (MWD) systems to US oil and gas
companies. MWD tools are used in the measurement of physical properties while drilling, such as
pressure, temperature and borehole trajectory.
The company, which expects to report a revenue of $230 million for 2023, has no debt, and its
acquisition is accretive to Alpha Dhabi and Adnoc Drilling from a “profitability, valuation multiple,
cash flow generation and dividend potential standpoint”, the companies said.
Adnoc Drilling, the largest national
drilling company in the Middle
East by rig fleet size, holds a
majority 51 per cent stake in the
JV with Alpha Dhabi holding the
remaining stake.
The Adnoc subsidiary will begin
incorporating the financial results
of the JV using the equity method,
starting from the company’s first-
quarter financial report.
Advancements in oil and gas technology, particularly in shale exploration, have taken the US to the
top global oil producer spot. The introduction of directional drilling and fracking led to America
becoming a net petroleum exporter in 2020 for the first time since at least 1949.
The global oilfield services market is expected to reach $153.49 billion by 2029, from an estimated
market size of $119.85 billion for this year, according to Mordor Intelligence.

North America is expected to be the largest market during the forecast period, owing to high drilling
and production activity in shale fields, the research firm said.
In the UAE, Adnoc Drilling has been increasingly focusing on the country’s unconventional oil and
gas resources as Adnoc pushes to increase its production capacity to five million barrels per day by
2027.
Abu Dhabi’s unconventional recoverable oil resources are estimated at 22 billion barrels of very
light and sweet crude. Light crude types are typically more valuable, easier to refine, and contain
greater quantities of hydrocarbons than heavier variants.
“We have been doing unconventional for the last five years but not to the depth which will potentially
[be seen] in the coming months and the years to come,” Mr Al Seiari told The National in May.
“It's an area that is [a] big focus for today … because [it] is going to be one of the main additional
sources for oil and gas [in the future].”
Alpha Dhabi acquired the stake in Gordon for $164 million in 2022 as part of its global expansion
strategy.
Since the acquisition, “we have supported its growth strategy in the US market and put the
foundations in place for expansion to the Middle East region”, Hamad Al Ameri, managing director
and group chief executive of Alpha Dhabi, said.
“Through this joint venture … we look forward to driving further value creation for the benefit of our
mutual stakeholders,” Mr Al Ameri added.

Egypt: DeepTech pens long-term deal with BP
Source: DeepTech
Deepwater services and intervention specialists, DeepTech, has won a three-year contract to
deliver rig support ROV services for BP on the West Nile Delta development offshore Egypt.
Two Work Class ROVs will be provided to directly support the drilling, completion and subsea
activities on this long-term contract which includes an option for further extension.
The first system will be
installed on a
deepwater drill-ship
and the second on a
platform supply vessel
(PSV) to support
drilling activities.
The West Nile Delta
development includes
five gas fields across
the North Alexandria
and West
Mediterranean
Deepwater offshore
concession blocks and
has been developed as
two separate projects
to accelerate gas
production in Egypt.
Managing Director of
DeepTech Oil
Services, Ahmed
Soliman, said: 'This
latest endorsement solidifies our position in the Mediterranean, demonstrating DeepTech’s proven
capabilities in delivering ROV services and solutions to Egypt and worldwide.
'The drilling activities will be supported from our Alexandria shore base and will significantly
contribute to local content and energy security and supply in the region. We are delighted to catapult
what we hope will be a long-standing and successful relationship with BP.'
Last month, DeepTech announced significant growth, with the addition of with three work class
ROVs to its fleet, bringing its total number of vehicles to 26.
Ahmed Soliman continued: 'We have enjoyed steady growth in the last five years. As well as our
recent fleet expansion, in 2020, we announced an extension to our custom-built facility in Cairo with
a new testing pool and crane. This added 3600m² and meant our engineers could try and test our
new technology in-house to maintain our position at the forefront of deepwater projects.
'We pride ourselves in operating the best equipment, with the best people, and are always looking
to improve our solutions and facilities to offer clients a seamless service.
'We very much look forward to working with BP and contributing to this important and high-quality
industry development.'

India First oil was Krishna Godavari Basin off shore
Written By Reema Sharma|
India announced its first oil extraction from a new discovery from state-owned ONGC's flagship
deep-sea project in the Krishna Godavari Basin. With four operational wells and a target of 45,000
barrels per day by June, this project is set to contribute 7% to crude oil and gas production in India.
Union Petroleum Minister Hardeep Puri, emphasising the strategic importance of this development
has told reporters, "I am sure that out of the 26 wells there, four wells are already operational. We
will not only have gas also in a short period of time, but by May or June we will hope to able to
produce 45,000 barrels per day, which will be 7 per cent of our total crude oil production and 7 per
cent of our gas production".
"ONGC commenced its 'First Oil flow to
FPSO', from Krishna Godavari Deep-Water
Block 98/2 (in Bay of Bengal) on 7 January
2024, nearing completion of Phase-2 of the
project. Phase-3, leading to peak Oil and
Gas production, is already underway and
likely to be over in June 2024. The 98/2
project is likely to increase ONGC's total Oil
and Gas production by 11 percent and 15
percent respectively," ONGC said in a post
on X.
PM Modi has also hailed the commencement of oil production from ONGC project in Krishna
Godavari basin saying that this is a remarkable step in India's energy journey and boosts the mission
for an 'Aatmanirbhar Bharat'.
Phase 3, leading to peak oil and gas production from the basin, is already underway and likely to
be over in June 2024. The 98/2 project is likely to increase ONGC’s total Oil and Gas production by
11 per cent and 15 per cent respectively.
India, the world’s third-biggest oil importer and consumer, is dependent on crude oil from various
sources in the global market to meet its domestic demand. “ONGC commenced its ‘First Oil flow to
FPSO’, from Krishna Godavari Deep-Water Block 98/2 (in Bay of Bengal) on 7 January 2024,
nearing completion of Phase-2 of the project.

NewBase January 11 -2024 Khaled Al Awadi
NewBase for discussion or further details on the news below you may contact us on +971504822502, Dubai, UAE
Oil prices firm as Middle East tensions heat up
Reuters +NewBase
Oil prices rose on Thursday after an oil tanker was boarded by an armed group in Oman, raising
the prospect of escalating conflict in the Middle East.
Brent crude futures gained $1.03, or 1.3%, to $77.83 a barrel by 0916 GMT and U.S. West Texas
Intermediate crude futures rose 98 cents, or 1.4%, to $72.35, though gains were capped by a
surprise build in U.S. crude stockpiles.
The United Kingdom Maritime Trade Operations (UKMTO) authority received a report on Thursday
that a vessel about 50 nautical miles east of Oman's coast was boarded by four to five armed
individuals.
The previous day Yemen-based Houthis mounted their largest attack yet on commercial shipping
lanes in the Red Sea and Israeli strikes in southern and central Gaza also intensified.
Oil price special
coverage
• Brent and WTI up about $1.50
• Armed individuals board tanker off Oman
• Signs of weakening oil demand cap gains

The United States and Britain hinted they would take further measures if the attacks continued. The
United Nations Security Council, meanwhile, passed a resolution demanding an immediate end to
the Houthi strikes
The oil benchmarks had settled lower on Wednesday after a surprise jump in U.S. crude stockpiles
raised concerns over demand in the world's largest oil market.
U.S. crude inventories (USOILC=ECI) rose by 1.3 million barrels to 432.4 million barrels in the week
ended Jan. 5, the EIA said on Wednesday, against analyst expectations for a draw of 700,000
barrels.
All eyes are now on U.S. inflation data, which will shape views on how soon the Federal Reserve
might cut interest rates.
"Slowing demand, unrest in Middle East and muted price reaction have producers, consumers and
market participants alike feeling paranoid about oil prices," Barclays said on Thursday as the bank
lowered its 2024 Brent forecast by $8 to $85 a barrel.
Meanwhile, Chinese refiners asked for less Saudi crude oil in February, people with knowledge of
the matter said, despite the world's top oil exporter announcing its biggest price cut in 13 months.
Looking ahead, China's customs administration will release December trade data on Friday, giving
a full-year picture of overall demand in the world's largest oil importer.

EIA expects relatively flat crude oil prices in 2024 and 2025
U.S. Energy Information Administration, Short-Term Energy Outlook, January 2024
We forecast average annual crude oil prices in 2024 and 2025 will remain near their 2023 average
because we expect that global supply and demand for petroleum liquids will be relatively balanced
over the next two years.
We expect the Brent crude oil price will average $82 per barrel (b) in 2024 and $79/b in 2025,
compared with its 2023 average of $82/b. We expect that the price of West Texas Intermediate
(WTI) will be slightly lower but generally follow the same path.
In the first quarter of 2024 (1Q24), we expect crude oil prices to rise somewhat, driven by OPEC+
production cuts leading to global stock draws of 810,000 barrels per day (b/d).
As a result of the stock draws, we forecast the price of Brent will increase from $78/b in December
2023 to $85/b in March 2024.
We expect that crude oil prices will gradually decrease after April 2024 with minor stock builds
because global production increases more than consumption. We forecast stocks will increase by
110,000 b/d from 2Q24 through 4Q24 and by 280,000 b/d in 2025.
We attribute the relatively small crude oil price changes in our forecast to continued reduced OPEC+
production. We forecast OPEC+ crude oil production will drop from 37.1 million b/d in 2023 to 36.4

million b/d in 2024. In 2025, we expect OPEC+ crude oil production to increase, averaging 37.2
million b/d. These values do not include Angola, which left OPEC in January 2024.
The latest OPEC+ agreement, announced on November 30, included 2.2 million b/d of new
voluntary cuts to its crude oil production target through March 2024.
These cuts are in addition to existing voluntary cuts and lower production targets determined at its
June 2023 meeting. We expect OPEC+ will produce less than its currently stated targets in 2024.
Non-OPEC+ countries, those countries not in or affiliated with OPEC agreements, produced an
estimated 52.0 million b/d of petroleum liquids in 2023.
We expect non-OPEC+ production to average 53.0 million b/d in 2024 and 53.9 million b/d in 2025.
We expect that non-OPEC+ production growth will be driven by U.S. production increasing by 0.4
million b/d in both 2024 and 2025.
The growth of global petroleum consumption over the past two years was driven by economic
growth and a return to pre-pandemic travel patterns, especially for international flights.
We forecast global petroleum consumption to increase by 1.4 million b/d in 2024 and 1.2 million b/d
in 2025, both of which are slightly less than the 10-year pre-pandemic average (2010–19).

NewBase Specual Coverage
The Energy world –January 11 -2024
CLEAN ENERGY
Canada’s Trans Mountain Oil Pipeline expansion
reportedly 95% complete
U.S. EIA, Environmental Systems Research Institute
Work on Canada’s Trans Mountain Pipeline expansion project is reportedly over 95% complete.
When it comes onstream, the expansion will nearly triple the pipeline’s current 300,000 barrels per
day (b/d) capacity to move crude oil from oil sands in landlocked Alberta to Canada’s Pacific Coast
for export to new customers in Asia or along the U.S. West Coast.
Although initially expected to come online early this year, the project could be delayed as much as
two years by a recent ruling, according to the project’s owner.
The existing Trans Mountain Pipeline currently offers one avenue for waterborne crude oil exports
out of Canada by moving crude oil from Edmonton in Alberta to Burnaby, a port near Vancouver on
the coast of British Columbia. The expansion
project aims to increase the pipeline’s current
capacity by 590,000 b/d, bringing the pipeline
to a capacity of 890,000 b/d.
The Canadian government acquired the
pipeline from Kinder Morgan for CA $4.5 billion
in 2018 and formed the Trans Mountain
Corporation (TMC) to oversee and manage the
pipeline and the expansion project.
The pipeline expansion, which consists of
added pipeline capacity that generally runs

along a similar route to the current pipeline, has faced several legal challenges from environmental
activists and Canadian First Nations groups.
Data source: Canada Energy Regulator, Canada's Energy Future
Canada’s crude oil production increased steadily for most of the last 13 years. Canada’s average
annual production of crude oil and condensate rose nearly 2.0 million b/d between 2009 to 2019. In
2020, the effects of the COVID-19 pandemic decreased crude oil production as crude oil prices
declined significantly.
Canada’s production has since resumed its growth trend. Canada’s production exceeded pre-
pandemic levels in 2022 when crude oil and condensate production averaged 4.9 million b/d,
according to data from the Canada Energy Regulator (CER).
Most new growth in Canada’s crude oil production is concentrated in the landlocked province of
Alberta. In 2022, Alberta’s crude oil production accounted for 82.7% of total crude oil production in
Canada, up from 76.1% in 2012.

Currently, more crude oil flows from Canda to the United States than to any other country by a wide
margin; U.S. imports from Canada have averaged about 3.7 million b/d since 2020, according to
our Petroleum Supply Monthly.
U.S. crude oil imports from Canada accounted for about 79% of Canada’s total crude oil production
during that time. Canada is also the largest source of crude oil imports to the United States, and
these imports primarily flow to refineries in the Midwest and the U.S. Gulf Coast.
CER’s refusal on December 5 to grant a variance request to Trans Mountain may delay the project
start date. After the decision was issued, Trans Mountain indicated the delay could last as long as
two years.
Forecasting the future: A look at Canada’s oil production scenarios
Last December, the Canada Energy Regulator (CER) released its Canada’s Energy Future
2021 report, an annual exploration of possible long-term scenarios for energy production and
consumption in Canada. This includes modeling oil production levels to 2050 under two sets of
assumptions about the future: an Evolving Policies Scenario (EPS) and a Current Policies Scenario
(CPS).
To the surprise of some, both scenarios highlight the resiliency of Canada’s oil production. They
project output remaining above 2021 levels until at least 2046, with the CPS projecting higher output
through 2050.
But every scenario forecast is only as good as its underlying assumptions. In this Quick Read, we’ll
look at each scenario’s assumptions, where they may be lacking, and why they model resilient
Canadian production.

EPS Assumptions
Broadly, the EPS assumes that Canadian and global climate policy action accelerates at a pace
consistent with historical trends.
In Canada, these assumptions include the carbon price increasing from $40 per tonne in 2021 to
$170/t in 2030), and then increasing by approximately $15/t each year until 2050 (nominal 2020
Canadian dollars). Emissions regulated under output-based carbon pricing mechanisms, such as
Alberta’s Technology Innovation and Emissions Reduction (TIER) regulation, are subject to
benchmarks tightened 2% annually from 2022 to 2050.
More stringent climate policy is anticipated to lower global demand for oil, pushing benchmark prices
steadily down from about US$70/barrel (bbl) in 2021 to approximately US$40/bbl.
Climate action is also expected to increase the uptake of low-carbon technologies thanks to their
reduced costs and energy efficiencies over time. This includes: significantly cheaper and more
efficient electric vehicle batteries; much less expensive low-carbon hydrogen production; steady
improvements to the cost and efficiency of renewable power generators; and significant uptake
of solvent-assisted oil sands extraction, among other advancements.
The EPS projects Canadian crude production to peak 17% above anticipated output in 2021 by
2032, followed by a steady decline to about 4% below 2021 output levels by 2050. Production isn’t
expected to drop below current levels until 2046.
CPS Assumptions
In contrast to the EPS, the CPS assumes that global and domestic climate policy stringency
matches today’s expectations. This means that the carbon price in Canada will increase to
$170/tonne by 2030 and remain steady until 2050, and TIER’s facility-specific emissions
benchmarks remain at their anticipated 2030 stringency from 2031 – 2050. Global oil demand is
expected to be much higher, keeping the Brent benchmark steady at around US$70/bbl for the
forecast period.
Unlike the EPS, the CPS anticipates only the gradual improvement of proven low-carbon
technologies with very little uptake of emerging cleantech. For example, electric vehicle battery
costs only fall 40% by 2050; renewable power capacity costs remain relatively more expensive than
in the EPS; and solvent-assisted oil extraction sees little-to-no take-up. The CPS projects Canadian

production to peak approximately 34% above anticipated 2021 output in 2044, followed by a modest
decline that will still be 32% above 2021 levels in 2050.
Why is oil production so resilient under these scenarios?
Simply put, extracting the next barrel from the oil sands—which accounts for an increasing
proportion of Canada’s production—does not cost very much once the initial (expensive) buildout
of projects is completed. Oil sands facilities have long lives, meaning that they can produce for
decades to come. As oil sands production increases, so too does the resiliency of Canada’s output.
Many global oil reserves do not have this luxury. For example, tight oil extracted in the United
States requires ongoing, costly drilling to maintain production levels.
Accordingly, even under scenarios projecting lower global oil demand, Canadian oil sands output
may be resilient if the following two conditions are met:
1. The cost of extracting the next barrel of oil is lower than not extracting it; and
2. The cost of extracting the next Canadian barrel is globally cost-competitive enough to
maintain market share.
To be clear, this is a simplification. But these are the kinds of dynamics that can make sense of
Canadian oil’s resiliency under even the EPS.
What about net-zero?
As acknowledged by the CER, neither the CPS nor the EPS align with net-zero emissions
assumptions despite Canada’s 2050 net-zero target.
That said, the CER will be including a net-zero scenario in future reports. While it is impossible to
know which underlying assumptions will closest match future realities, having a net-zero scenario
is helpful for policymakers as they analyze trade-offs in pursuit of Canada’s climate targets.

Nonetheless, the CPS and EPS are valuable in their own right; if the actual future—much of which
is out of Canada’s control, such as global climate policy, commodity prices, and technological
development—aligns with either of these scenarios’ assumptions, they will have provided helpful
insight into oil’s resiliency and how policymakers can respond.
Canada’s crude oil pipeline network has three different types of pipelines:
• Gathering pipelines move crude oil from the wellhead to storage and on to upgraders or
refineries. Provincial regulators typically regulate these facilities.
• Feeder pipelines transport crude oil from storage tanks and processing facilities to
transmission pipelines. Provincial regulators typically regulate these facilities.
• Transmission pipelines transport crude oil to refining markets, often across provincial or
international boundaries. Transmission pipelines are typically regulated by the CER.
If a pipeline crosses provincial or international boundaries, it is regulated by the CER. This report focuses on
transmission pipelines because these are generally the ones crossing provincial or international boundaries.
Typically, if a pipeline is contained within a province, it is under the jurisdiction of a provincial regulator unless
deemed a federal undertaking.Footnote2
The CER regulates approximately 68 000 km of operating pipelines, including 19 142 km of operating oil
pipelines. The map below shows the major oil pipelines regulated by the CER.

NewBase Energy News 11-January - Issue No. 1689 call on +971504822502, UAE
The Editor:” Khaled Al Awadi” Your partner in Energy Services
NewBase energy news is produced Twice a week and sponsored by Hawk Energy Service – Dubai, UAE.
For additional free subscriptions, please email us.
About: Khaled Malallah Al Awadi,
Energy Consultant
MS & BS Mechanical Engineering (HON), USA
Emarat member since 1990
ASME member since 1995
Hawk Energy member 2010
www.linkedin.com/in/khaled-al-awadi-38b995b
Mobile: +971504822502
khdmohd@hawkenergy.net or khdmohd@hotmail.com
Khaled Al Awadi is a UAE National with over 30 years of experience in the Oil & Gas
sector. Has Mechanical Engineering BSc. & MSc. Degrees from leading U.S.
Universities. Currently working as self leading external Energy consultant for the
GCC area via many leading Energy Services companies. Khaled is the Founder of
the NewBase Energy news articles issues, Khaled is 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 over
1400 popular articles to his credit. He is proactively engaged in creating mass awareness on renewable
energy, waste management, plant Automation IA and environmental sustainability in different parts of the
world. Khaled has become a reference for many of the Oil & Gas Conferences and for many Energy program
broadcasted internationally, via GCC leading satellite Channels. Khaled can be reached at any time, see
contact details above.

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