New base special 30 april 2014

Copyright © 2014 NewBase www.hawkenergy.net Edited by Khaled Al Awadi – Energy Consultant All rights reserved. No part of this publication may be reproduced,
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NewBase 30 April 2014 Khaled Al Awadi
NewBase For discussion or further details on the news below you may contact us on +971504822502 , Dubai , UAE
Kuwait to launch pilot solar project
Source – KFAS
Kuwait Foundation for the Advancement of Sciences (KFAS) has adopted a pilot project using the systems
of photovoltaic cells to generate solar power in 150 houses, said a report.
The project is part of KFAS' new strategy which focuses on contributing to the application of scientific
solutions to address priority issues, including water, energy and the environment for the best interest of the
country, said Kuwait News Agency (Kuna).
It aims to reduce the loads on the electrical grid and maintaining the oil resources by burning less fuel in the
production of electrical power, especially in peak times as a result of the use of the photovoltaic cells as well
as the reduction of environmental impacts due to emissions of greenhouse gases.
Once the project gets completed in the next three years, 7,027 barrels of oil would be provided every year
worth up to KD221,000 ($784,718), anticipating multiplication of this value in the peak hours.

ADNOC strikes deal with Chinese CNPC on oil exploration
April Yee , TheNational.ae
China is set to secure oil exploration rights in Abu Dhabi, giving the world’s top oil importer access
to one of the world’s most stable oil producing countries.
China National Petroleum Company has established a joint venture with
Adnoc to develop crude in the emirate, the state news agency Wam said without specifying any
concessions that have been awarded. Since 2012, CNPC has been appraising the technical
potential of five onshore and two offshore undeveloped blocks covering much of the area west of
Abu Dhabi’s legacy fields.
For China, the award marks a breakaway from its role as a cheap go-to for construction projects –
such as the Fujairah pipeline that bypasses the Strait of Hormuz – and a producer willing to go
where others did not dare: Iraq, Sudan, Afghanistan.
“The real strength of Chinese upstream oil companies is that they appear to have an unlimited
appetite for political risk,” said Chris Gunson, an oil and gas lawyer at Pillsbury in Abu Dhabi. “In
Abu Dhabi there is no political risk, which means that everyone can get involved and the margins
are extremely low.
“So when you think about why China would want to be involved, it’s an interesting diversification
away from politically messy places to one of the most stable and reliable producers.”
The new joint venture, which has been named Al Yasat and will be 40 per cent owned by CNPC,
comes as Abu Dhabi ponders the future of its legacy contracts and its relationships with western
powers.
A source with knowledge of Abu Dhabi’s oil industry said that it would be “extremely unlikely” that
Al Yasat would be given fields that are already producing oil but instead would be awarded riskier,
less developed assets. The legacy players – Total, ExxonMobil, BP, Partex and Royal Dutch Shell
– lost the rights to an onshore concession responsible for half of the emirate’s output at the end of
its 75-year run in January.
Since it began producing oil half a century ago, Abu Dhabi has gradually diversified its partners,
bringing in the Japanese) and Austria’s OMV, Germany’s Wintershall, and Korea National Oil
Company. Adnoc even floated the possibility of granting small fields to Mubadala Petroleum, the
government-owned company that explores for oil and gas outside the country, in an agreement
signed late last year.
New partners must be approved by the Supreme Petroleum Council, the emirate’s top energy
decision-making body that includes members of the ruling family. aAmong the considerations are
technical skills as well as alignment with the world’s growing economic and political powers in
Asia.
CNPC had originally hoped to launch drilling in Abu Dhabi in early 2013, but progress on Abu
Dhabi-China energy cooperation stalled as delays arose with the strategic Fujairah pipeline built
by a CNPC subsidiary.

The pipeline, which allows all of the emirate’s current onshore production to bypass the Strait of
Hormuz bottleneck by connecting to Fujairah, was plagued by technical problems stemming from
late payments.
“Adnoc is very happy with their Chinese
partner,” Suhail Al Mazrouei, the Minister
of Energy, said late last year. “They are
keen on the exploration and doing the
work in the ground to test their credibility
on the ground, rather than just being a
partner.”
Adnoc is expected to send its
recommendation for the onshore
concession, operated by Abu Dhabi
Company for Onshore Oil Operations
(Adco), to the Supreme Petroleum
Council within weeks.
An ADNOC drilling rig in Abu Dhabi. Baoji Oilfield
Machinery's oilfield services contract is a first for a
Chinese state oil firm in the emirate

GlassPoint first in the world to deploy new solar sensors
BYTIMES NEWS SERVICE
GlassPoint Solar, the leader in solar enhanced oil recovery (EOR), has become the first company
in the world to deploy new optical sensors developed by the DLR Institute of Solar Research and
Black Photon Instruments (BPI), a spin-off of Fraunhofer
The sensors, optimised for desert environments, were installed at GlassPoint's 7MWth solar EOR
project at an oilfield in southern Oman to provide precise real-world solar energy data used to
enhance performance
Benefits
The new BPI CSR460 sensors measure circumsolar radiation in environments prone to extreme
heat and high levels of airborne dust, dirt and sand, which can deflect the sunlight and reduce the
efficiency of a solar thermal system. By determining the influence of circumsolar radiation on plant
performance, GlassPoint can improve the accuracy of its performance models and the efficiency
of the enclosed trough.
"GlassPoint is committed to leading the way in Middle East solar data and field design," said Ben
Bierman, chief operating officer of GlassPoint. "We designed the enclosed trough technology from
the ground up to overcome high winds and dust common throughout the Gulf region. Being the
first to deploy these advanced sensors gives us superior insights into the value of the energy from
sunlight as the sunshape changes over the course of the day
Solar EOR project
The data helps optimise the performance of our solar EOR project in Oman and can be applied to
improve the design of future large-scale projects."
Results from the first year of operations have proven that GlassPoint's technology thrives in
challenging desert conditions. Actual performance of the GlassPoint system matched output
models within a few percent and steam production continues to exceed contracted targets. During
a severe dust storm last year, the facility continued to operate successfully and produced the
rated amount of steam for the day.
GlassPoint continues to collaborate with solar industry leaders such as DLR and Black Photon
Instruments to develop best practices for solar energy deployment in dusty operating conditions
throughout the world.
The sensors were optimised for desert environments and
installed at GlassPoint’s 7MWth solar EOR project at an
oilfield in southern Oman to provide precise real-world
solar energy data used to enhance performance .

China stalls petchem as US competition grows
Reuters
China's top refiner Sinopec Corp is scaling back billions of dollars in petrochemical investments in
the face of growing US competition in the sector and rising local opposition to oil and gas plants
over environmental concerns.
The slowdown marks a break from two decades of expansion led by China's state energy majors,
which have placed self-sufficiency above profitability and environmental impact to chase robust
demand growth in the world's second-largest economy.
The scaleback by Sinopec, Asia's largest refiner and China's largest petrochemical producer,
follows an earlier reduction in its 2014 spending budget in response to the nation's slowing
economy and the poor performance of its chemical division.
Rival state refiner, PetroChina, has taken similar steps, stalling a $13 billion venture jointly
proposed by Shell in east China and another one in Guangdong with state oil company Petroleos
de Venezuela SA.
In the latest sign of a broad slowdown, Sinopec held up its plans to build a $3.1 billion ethylene
plant in Qingdao city, a company source said on Monday, after a pipeline blast there last year
killed 62 and threw into question its viability as a site for another petrochemical complex.
"It's a sector scaleback," said a Beijing-based industry official with an international energy major,
which works closely with Sinopec. The official declined to be named because he's not authorized
to speak to the media.
"Sinopec realises that the traditional naphtha-based ethylene crackers are losing their competitive
edge ... plus the growing public resistance to big petrochemical plants."
On top of the resistance of Chinese communities, cheap petrochemical building blocks from the
US threaten to overwhelm the sector. US shale gas crackers can produce ethylene at less than
half the cost of the naphtha-fed crackers typical in Asia, industry experts say.

Over the next five to 10 years, as many as a dozen world-scale, gas-based plants are expected to
start up in the US, including some built by Asian firms like Formosa Petrochemical Corp,
according to Vince Sinclair, head of Asia-Pacific petrochemicals research at consultancy Wood
Mackenzie.
MEGA PROJECTS OUT
Sinopec has shelved or postponed proposals for nearly 4 million tonnes of annual capacity of
ethylene, key building blocks for plastics and synthetic fibres, industry sources said, potentially
boosting China's petrochemical imports from companies such as Saudi's Sabic and US firm Dow
Chemical Co.
Sinopec spokesman Lu Dapeng acknowledged the company's scaleback, but declined to detail
the extent or the duration of specific project delays.
Local governments, traditionally strong lobbyists for refineries or ethylene plants, are no longer as
enthusiastic for such mega projects after Beijing last year started to link their political careers with
ensuring environmental protection rather than just economic growth.
"Now they (local authorities) have become wary of the big chemical projects," said Lu

Aibel starts tenth shutdown at Oseberg-N. Sea
Press Release, April 29, 2014; Image: Statoil
Aibel announced that during the weekend the Company has started shutdown operations at
Oseberg oil field in the North Sea. This also marks the beginning of a hectic period with many
shutdowns for Aibel.
“Now there will be full activity at both night and day for nearly three weeks,” says Aibel’s shutdown
coordinator Arild Tveit.
Aibel is involved with Oseberg through a framework agreement with Statoil for maintenance and
modifications and has permanent staff in rotation offshore. However, during the shutdown, activities will be
higher. Around 300 Aibel employees will be in action in the field at any time.
Replacing the Sture valve
The installations will be emptied of oil and gas. Work that cannot be performed whilst the fields are in
production is now possible. In total, more than 40,000 working hours have been planned across the Oseberg
field centre, Oseberg south, C and east.
The majority of the hours will be implemented at the Oseberg field centre. Aibel will, among other things,
replace the Sture valve. This is an important activity. The new valve must be installed and operational
before production resumes.
“Otherwise no oil will be supplied from Oseberg to Sture,” the shutdown coordinator explains.
“Aibel will also replace the Veslefrikk valve. The flare system will be upgraded with more than 50 new flare
pipes. The flare system is the safety system at the platform. We have replaced parts of the system during
three shutdowns so far. This time the work is extensive,” he says.
Enormous logistics
Aibel began preparing for the shutdown in August 2013. Nearly 300 engineers have been involved in the
work to plan and find new solutions for the required upgrades.

“The engineers handed over their work packages in January. Since then the focus has been on the detailed
planning of the work that will be done out there,” Tveit explains.
Prefabrication of pipes and structures began at the end of 2013. Offshore has been working to prepare for
the shutdown for several months. All parts and tools have to be in place.
Extensive experience
Aibel has been at Oseberg continuously for 20 years through different framework agreements. The
shutdown in 2014 will be the company’s tenth in the field.
“We have many experienced employees in action. The projects have been carefully planned and risks have
been assessed. HSE is the first thing on our mind when we get up in the morning and the last thing on our
mind as we go to bed. Naturally, we are always concerned about unexpected events and delays but we are
as well prepared as we can be,” the shutdown coordinator says.
Over the next few months Aibel will also be involved with major shutdown at Hammerfest LNG, Statfjord
and Gullfaks.
About the Oseberg Field :-

BP and Shell at work on Greater Clair in UK West Shetland waters
The UK super major BP and its partners, Royal Dutch Shell (Shell), ConocoPhillips and Chevron,
are getting now a better picture of the giant Clair reservoir to the point to prepare Greater Clair as
the third phase of development in the West Shetland waters of the UK.
Discovered in 1977, Clair had been left undeveloped more than 20 years because of the size and
complexity of its reservoir. Located 75 kilometers west of the Shetland Islands in Scotland, Clair
still lies in the shallow
water of the UK
Continental Shelf by only
140 water depth.
Although Clair was easy
to reach, the
fragmentation of the
reservoir in multiple
pockets brought up
immediate challenges.
At that time the drilling
technology, nearly
exclusively vertical, was
yielding poor results even
though the in-place
reserves were quickly
estimated over 5 million
barrels of crude oil.
Because of its size and
complexity, Clair finalized
to concentrate as
stakeholders only major
companies in the joint
venture and among
them, the ones with the
most advanced offshore exploration and production expertise.
Currently Clair working interests are shared between:
- BP 28.6% is the operator
- Shell 28% in including Enterprise Oil Ltd
- ConocoPhillips 24%
- Chevron 19.4%
With Clair Phase-1 in operation since 2005 and Clair Phase-2 (Clair Ridge) to start operation in
2016, BP and its partners Shell, ConocoPhillips and Chevron foresaw the Clair full field
development to go beyond 2050.
BP and Shell appraise Greater Clair 40 years reserves

In this perspective any further investment in Greater Clair for the third phase was requiring the
partners to get a better understanding of this Clair field covering 220 square kilometers and with
in-place reserves revised upward to 8 million barrels of crude oil.
In March 2013, BP and its partners had voted for a $500 million two-year appraisal program of the
Clair oil and gas field.
Considering that each phase
of Clair field development is
costing between $5 and $7
billion capital expenditure,
the appraisal program is
expected completed the
experience accumulated
from the first phases to help
prioritizing where to invest in
the field and optimizing the
exploration – production
concept for full field
development.
In addition to the better
understanding of the
reservoir structure, the
technology made significant
progress enabling a more
efficient exploration and a
higher recovery rate from the in-place reserves.
On the exploration, BP and its partners count of the horizontal drilling technology to trace
accurately the fragmented pockets of oil in the reservoir.
Then to boost the production, BP is planning to use its proprietary LoSal low salinity water
injection process.
Discovered in Alaska in the Endicott field, where the sea water has a lower salinity, the principle of
injecting low salinity water has proven to have a direct impact on the recovery rate of the crude oil
reserves.
In this context and although Chevron put on hold its similar Rosebank project because of spiraling
costs, BP and its partners, Shell, ConocoPhillips and Chevron intend to move forward with
Greater Clair, the Clair Phase-3, as this basin concentrates 17% of the UK oil and gas fields
reserves.

GDF Suez: First major piece of infrastructure sails out to Cygnus
Press Release, April 29, 2014
GDF Suez E&P UK has reported that the latest milestone in the Cygnus gas field project took
place as the first piece of major infrastructure sailed out from Isleburn’s facilities at Nigg Energy
Park.
The beginning of the subsea isolation valve and WYE structures’ journey to the Cygnus site in the Southern
North Sea, 150 kilometres off the coast of Lincolnshire, brings the project a crucial step closer to
completion.
The Cygnus field – operated by GDF SUEZ E&P UK (38.75%) with partners Centrica Energy (48.75%) and
Bayerngas UK (12.5%) – is the largest discovery in the Southern Gas Basin in the last 25 years with gross
reserves of approximately 18 billion cubic metres. First gas is targeted for late 2015 and by 2016 the field
will be the second largest individual gas producer in the UK.
The subsea structures will travel 575 km on the Ugland barge UR-2 and both structures will be installed
using the Seaway Heavy Lifting vessel, Stanislav Yudin.
The SSIV manifold weighs 156 tonnes and the WYE manifold
weighs 548 tonnes. It is one of the largest subsea manifolds to be
installed in the North Sea, equivalent in size to 20 double decker
buses parked side by side.
All components of the structures were procured by GDF SUEZ
E&P UK and assembled by Isleburn. Business and Energy
Minister Michael Fallon MP recently visited the yard to view the
structures as part of No. 10’s Infrastructure Day, in which the
Cygnus development was the only exploration project featured.
Related: UK Energy Minister visits Nigg yard to see Cygnus project progress
Cygnus Alpha Wellhead topsides
ready for site move. Site move of the
Cygnus Alpha Wellhead topsides

Jean-Claude Perdigues, Managing Director of GDF SUEZ E&P UK, said: “This is a pivotal point in the
project as the first structure sails out from the UK. It heralds the beginning of structure deployment offshore
for our flagship Cygnus development as we continue our drive to achieve first gas from the field next year.
The experience and expertise of the team at Isleburn has resulted in smooth delivery of these subsea
structures and contributes to our continued project success. The contract with Isleburn was awarded on
20th December 2012.”
Isleburn were delighted to play an important role in this flagship Cygnus project and their Senior Project
Manager, Ray Goller, commented: “It was a privilege to be involved in this ground breaking project and
we were pleased to work closely and successfully with our clients to ensure we satisfied everyone’s key
indicators of safety, timescale and quality of work over the term of the contract.”
Greg McKenna, Director of Non-Operated Assets at Centrica Energy, said: “To see the first offshore
infrastructure destined for the Cygnus field sail out marks a major milestone in a development which
represents an important source of UK jobs and, at peak, will produce enough gas to meet the demand of 1.5
million UK homes.”
Gerry Harrison, Managing Director of Bayerngas UK, said: “We are delighted to see this significant event
on schedule and congratulate Isleburn on the safe completion of their work.”
The Cygnus Partnership is led by operator GDF SUEZ E&P UK Ltd (38.75%) with partners Centrica
(48.75%) and Bayerngas (12.5%).
GDF SUEZ E&P UK is the operator of the Cygnus development, one of the most significant undeveloped
gas fields in the North Sea and employs more than 300 staff and contractors in offices in London and
Aberdeen. Cygnus is located in the Southern North Sea, 150 kilometres off the coast of Lincolnshire. It has
gross 2P (proved and probable) reserves of approximately 18 billion cubic metres. First gas is targeted for
late 2015.

Italian gas deals with Azerbaijan break traditional oil-link
Reuters/Milan
A handout photograph from Eni shows their operation in the Karachaganak gas condensate field in
northwest of Kazakhstan. Italy is counting on its new gas contracts with Azerbaijan to wriggle free of
traditional oil-linked pricing mechanisms.
Italy is counting on its new gas contracts with Azerbaijan to wriggle free of traditional oil-linked
pricing mechanisms, used by its two biggest suppliers Russia and Algeria, in a bid to bring down
energy prices.
Europe’s fourth-biggest economy has struggled to win access to market-priced gas supplies,
partly due to reluctance by its main suppliers Russia and Algeria to rewrite profitable oil-linked
deals, as well as Italy’s lack of alternative sources.
But the BP-led Shah Deniz II development vying to grab a share of Europe’s gas market by 2019
is taking steps to undercut rival suppliers Russia and Algeria by offering long-term deals tied to
prices on domestic spot markets, including Italy’s developing PSV hub.
The Azeri project will pump 16bn cubic metres (bcm) of gas to Turkey and the European Union,
where energy companies have contracted to buy 10 bcm. “The Italian deals are similar to the
contract between Qatar and (Belgium’s) Distrigas for long-term LNG supplies,” one source with
knowledge of the matter said.
In that deal, Distrigas, now owned by Italy’s ENI, initially paid a price tied to a barrel of crude oil for
shipments of Qatari liquefied natural gas (LNG). As Belgium’s Zeebrugge gas hub became a key
trading point in Europe and liquidity rose, Qatar converted its pricing structure to one fully linked to
local gas prices.
A similar move in Italy would help remove the risk of Italian gas buyers losing billions of euros on
oil-linked deals when prices for the two commodities diverge, as has been the case in recent
years.
European utilities bound by long-term supply deals from Russia and Algeria tied to oil have lost
out in recent years, as the development of regional gas trading hubs meant that consumers
bought the gas from utilities at a lower price than these had bought it from the producer.
Top gas buyers such as Italy’s ENI and Germany’s E.ON lost billions of euros in such oil-linked
deals.

To prevent such losses in future, France’s GDF Suez, which with 2.6 bcm is the single biggest
buyer of Shah Deniz II gas, already secured a 100% indexation to prices at freely traded gas hub
TTF in the Netherlands, several sources with knowledge of that deal said.
Other buyers of Azeri gas, like Italy’s Enel, Hera Trading, as well as Switzerland’s Axpo, who
signed deals to buy around 5 bcm per year, will pay a price fully linked to traded gas prices at
Italy’s PSV hub, two sources with knowledge of the contract between Shah Deniz II and the gas
buyers said.
Such an arrangement would mean that Italian buyers would pay a price reflective of supply and
demand for gas in their home markets, instead of to globally traded and costlier crude oil. But in
order to qualify for hub-linked prices, Italy’s thinly traded PSV hub must first hit certain liquidity
targets to demonstrate that it is a viable alternative to oil benchmarks, according to a clause in the
contract.
Liquidity in Italy has for years been hampered by a lack of transparency and the dominant market
position held by gas incumbent ENI. “Greater efforts need to be taken to increase traded volumes,
especially with Algerian volumes under pressure and Libya in a bad state,” said Claudio Gianotti,
head at World Energy, a gas and power trading company.
Although still falling short of targets, traded volumes at the PSV hub have seen steady growth this
year, and the promise of cheap Azeri supply from 2019 may incentivise firms to become
increasingly active at the hub.
Falling short of liquidity targets will see Italian buyers revert to paying a price based on a 20%
indexation to crude oil, with the remaining 80% tied to spot gas prices at the TTF hub in the
Netherlands. Long-term gas deals struck decades ago used to be fully pegged to crude prices, but
the development of liquid gas trading hubs has gradually eroded oil’s price-setting role.
A virtual gas trading point, the PSV was created in 2003 but a lack of liquidity, competition and
pipeline bottlenecks have kept Italian spot prices at a premium to European peers. Italy’s gas
market churn rate, which shows how many times gas is traded before it is consumed, rose to
three in 2013, compared with 19 in the Netherlands and 23 in Britain. A churn rate of 10 is
considered a threshold of a mature market. It is unclear what precise liquidity targets Shah Deniz
II has set in the contract with Italian buyers.

Kazakhstan: Eni doubtful on Kashagan output in 2015 - blames welding
Source: Reuters via Yahoo! Finance
Italian oil major Eni is not counting on any production from Kazakhstan's huge Kashagan oilfield
this year or possibly next due to faulty welding at the $50 billion project, its CEO designate said.
Production at Kashagan, the world's biggest oil find in 35 years, started last September but was
stopped in early October after gas leaks were found in the pipeline network. 'It's worse than we
considered. We have already put in place contingency plans to cover a possible lack of production
in 2015,' Claudio Descalzi told analysts in a conference call on Tuesday after Eni reported a drop
in first-quarter profits.
Descalzi, the current head of exploration and development who is slated to take over as CEO in
May, said the two gas and oil pipelines at the plant would most likely have to be replaced. 'The
problem is related to some spot hardness points on the pipes but mainly to the welding,' he said.
Recent tests in Britain, France and Italy have shown that the pipes' carbon steel material was fit to
withstand the hostile Kashagan conditions, he added.
The Kashagan consortium is considering changing the width of the oil and gas pipelines that run
to shore from their current 28-inch diameter to 20 inches, Descalzi said, adding that it may make
them easier to fit. He said the extra costs and the timeframe involved in replacing the pipelines
would be known in June.
The North
Caspian
Operating
Company
consortium is led
by Exxon Mobil,
Royal Dutch
Shell, Total, Eni
and Kazakh
state oil firm
KazMunaiGas.
Saipem, an oil
service company
43 percent-
owned by Eni,
was involved in
the laying and
welding of the
project's
onshore and
offshore
pipelines.

Renewable electricity generation projections sensitive to cost,
price, policy assumptions
www.eia.gov/todayinenergy
Renewable electricity generation in the United States is projected to grow by 69% from 2012 to 2040 in the
Annual Energy Outlook 2014 (AEO2014) Reference case, including an increase of more than 140% in
generation from nonhydropower renewable energy sources. While projected hydropower generation is
almost completely insensitive to alternative assumptions related to cost, policy, and general economic
conditions, the level of nonhydropower renewable electricity generation varies significantly with different
assumptions.
Source: U.S. Energy Information Administration, Annual Energy Outlook 2014, Issues in Focus
Note: GHG denotes greenhouse gases
The AEO2014 Reference case is based on current laws and policies (including the expiration of
laws with scheduled expiration dates), and known technology and demographic trends.
Nonhydropower renewable generation projections are highly sensitive to assumptions regarding
policies that affect the attractiveness of renewable technologies (such as the production tax credit
for certain renewable generation technologies), the costs and performance of the technologies,
the costs of competing generation sources, and general macroeconomic conditions. In order to
address such uncertainties, AEO2014 includes alternative cases that provide insight regarding the
direction and magnitude of sensitivities in the projections to shifts in assumptions.

These side cases include:
• An extension of policies such as the production and investment tax credits through the end of the projection
period (No Sunset)
• The application of a $25/metric ton fee on carbon dioxide emissions that increases 5% each year until the
end of the projection period (GHG25)
• Higher/lower growth in demand for electricity resulting from higher/lower economic growth rates
(High/Low Macroeconomic Growth)
• Lower renewable technology costs (Low Renewable Technology Cost)
• Higher/lower natural gas prices resulting from lower/higher oil and gas resource assumptions (High/Low Oil
and Gas Resource)
Changing these key assumptions can significantly affect projections for nonhydropower renewable
electricity, particularly in the later years of the projection. For example, in the GHG25 case, total
nonhydropower renewable generation in 2040 is 83% higher than in the Reference case, and in the High Oil
and Gas Resource case, total nonhydropower renewable generation in 2040 is 12% lower than in the
Reference case.
Although nonhydropower renewable generation more than doubles between 2012 and 2040 in the AEO2014
Reference case, its contribution to U.S. total electricity generation is still just 16%, well behind the natural
gas and coal shares of 35% and 32%, respectively. In contrast, renewables account for 24% and 27%,
respectively, of total electricity generation in 2040 in the No Sunset and GHG25 cases. In fact, renewable
penetration of electricity supply in both cases meets or surpasses 16% by 2020, which is the level attained in
the Reference case by 2040. Some additional results include the following:
• The responsiveness of EIA's nonhydropower renewable electricity projections to these particular
uncertainties is not necessarily symmetric. Changing these key assumptions can lead to significantly
higher levels of renewable electricity generation, but generally do not result in renewable
generation levels significantly below Reference case projections.
• Changing key assumptions generally affects long-term nonhydropower renewable electricity
projections to a much greater degree than near-term projections.
• Individual renewable technologies are not proportionately affected by changes in key assumptions.
Solar and wind generators are generally more responsive to assumption changes than biomass,
waste, or geothermal generators.
Additional analysis can be found in the AEO2014 Issues in Focus discussion of variations in
nonhydropower renewable electricity projections.
This Issues in Focus article is intended to emphasize that there is a great deal of uncertainty related to
factors such as policy, project costs, and natural gas prices—and that a shift in any of these factors could
significantly change EIA's renewable projections, generally in the positive direction. However, even in the
AEO2014 Reference case, EIA projects that more than 15 gigawatts (GW) of new wind capacity would be
able to take advantage of the extension of the production tax credit, which is available to projects starting
construction or in significant development before January 1, 2014. In comparison, recent reports from the
American Wind Energy Association indicate that as much as 12 GW of wind projects met that deadline and
are currently in the construction pipeline.

Tanzania: Swala Energy awards Tanzanian seismic survey contract
Source: Swala Energy
Swala Energy has announced that its 65.13% owned subsidiary Swala Oil & Gas (Tanzania) has awarded
the contract to carry out the seismic acquisition programme over the Kilosa-Kilombero and Pangani
licences to Polaris (Tanzania). The contract has been awarded on the basis of an extension to its 2013
contract.
Polaris carried out the
seismic acquisition
programme over the two
licences in 2013, in the
course of which the Company
surveyed five basins and
identified the Kito Prospect.
The minimum commitment
work programme for which
the contract has just been
awarded includes up to 500
km of 2D seismic over the
Kilosa-Kilombero licence
and a further 200 km of 2D
seismic over the Pangani
licence. The Company’s
efforts are focused on the
Kilombero basin in Kilosa-
Kilombero and on the Moshi
basin in Pangani. Polaris was
selected on the basis of its
excellent work during the
2013 survey, including high
acquisition rates, high-quality
data, good working relations
with the local community and
an excellent safety record.
Polaris will be conducting the
2014 survey over areas it has
a good working knowledge
of.
Dr. David Mestres Ridge,
CEO of Swala, said 'We are
pleased to have been able to
again engage the services of
Polaris. Their 2013 survey of
the two licences was very
competent and the knowledge that they gained of the areas of operations should help them progress the
survey over the prospects and leads that their earlier survey has identified'.
Swala Energy's licences in Kenya and Tanzania - including
Kilosa-Kilombero and Pangani

NewBase For discussion or further details on the news below you may contact us on +971504822502 , Dubai , UAE
Your partner in Energy Services
Khaled Malallah Al Awadi,
MSc. & BSc. Mechanical Engineering (HON), USA
ASME member since 1995
Emarat member since 1990
Energy Services & Consultants
Mobile : +97150-4822502
khalid_malallah@emarat.ae
khdmohd@hotmail.com
Khaled Al Awadi is a UAE National wiKhaled Al Awadi is a UAE National wiKhaled Al Awadi is a UAE National wiKhaled Al Awadi is a UAE National with a total of 24 yearsth a total of 24 yearsth a total of 24 yearsth a total of 24 years of experience in theof experience in theof experience in theof experience in the Oil & Gas sector. Currently working asOil & Gas sector. Currently working asOil & Gas sector. Currently working asOil & Gas sector. Currently working as
Technical Affairs Specialist for Emirates General Petroleum Corp. “Emarat“ with external voluntary Energy consultation forTechnical Affairs Specialist for Emirates General Petroleum Corp. “Emarat“ with external voluntary Energy consultation forTechnical Affairs Specialist for Emirates General Petroleum Corp. “Emarat“ with external voluntary Energy consultation forTechnical Affairs Specialist for Emirates General Petroleum Corp. “Emarat“ with external voluntary Energy consultation for
the GCC area via Hawk Energy Service as a Uthe GCC area via Hawk Energy Service as a Uthe GCC area via Hawk Energy Service as a Uthe GCC area via Hawk Energy Service as a UAE operations base , Most of the experience were spent as the Gas OperationsAE operations base , Most of the experience were spent as the Gas OperationsAE operations base , Most of the experience were spent as the Gas OperationsAE 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 , heManager in Emarat , responsible for Emarat Gas Pipeline Network Facility & gas compressor stations . Through the years , heManager in Emarat , responsible for Emarat Gas Pipeline Network Facility & gas compressor stations . Through the years , heManager in Emarat , responsible for Emarat Gas Pipeline Network Facility & gas compressor stations . Through the years , he has developedhas developedhas developedhas developed
great experiences in the designing &great experiences in the designing &great experiences in the designing &great experiences in the designing & constructingconstructingconstructingconstructing of gas pipelines, gas metering & regulating stations and in the engineering of supplyof gas pipelines, gas metering & regulating stations and in the engineering of supplyof gas pipelines, gas metering & regulating stations and in the engineering of supplyof 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 Mroutes. Many years were spent drafting, & compiling gas transportation , operation & maintenance agreements along with many Mroutes. Many years were spent drafting, & compiling gas transportation , operation & maintenance agreements along with many Mroutes. Many years were spent drafting, & compiling gas transportation , operation & maintenance agreements along with many MOUs forOUs forOUs forOUs for
the local authorities.the local authorities.the local authorities.the local authorities. He has become a reference for many of the Oil & Gas Conferences held in the UAE andHe has become a reference for many of the Oil & Gas Conferences held in the UAE andHe has become a reference for many of the Oil & Gas Conferences held in the UAE andHe has become a reference for many of the Oil & Gas Conferences held in the UAE and Energy program broadcastedEnergy program broadcastedEnergy program broadcastedEnergy program broadcasted
internationally , via GCC leading satelliteinternationally , via GCC leading satelliteinternationally , via GCC leading satelliteinternationally , via GCC leading satellite ChannelsChannelsChannelsChannels ....
NewBase : For discussion or further details on the news above you may contact us on +971504822502 , Dubai , UAE
NewBase 30 April 2014 K. Al Awadi

New base special 30 april 2014

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New base special 30 april 2014