New base 489 special 30 november 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 November 2014 - Issue No. 489 Khaled Al Awadi
NewBase For discussion or further details on the news below you may contact us on +971504822502 , Dubai , UAE
UAE powers up with energy growth
The National + NewBase
Power generation in the UAE will increase by more than 1.5 gigawatts in 2017, enough to power
around 150,000 homes, according to a new report.
The State of Energy Report in the UAE 2015, prepared by the Dubai Carbon Centre of Excellence
and the United Nations, highlights energy projects across the UAE focusing on energy
diversification and government policy.
The report reveals that the UAE will increase power generation with a mix of energy sources from
natural gas to solar and nuclear power.
From 2008 to 2012, national power demand grew 37 per cent. Abu Dhabi increased its power-
generating capacity by 43.6 per cent and Dubai increased capacity 44.5 per cent. The UAE’s
energy demand is growing at about 9 per cent a year.
One of the three projects listed in the report is the Shah Gas Development, a joint venture
between Abu Dhabi National Oil Company (Adnoc) and Occidental Petroleum. The project is the
first of its kind in the country, and is anticipated to come online early next year.
Located in Abu Dhabi’s Liwa desert, the Shah marks the country’s first venture into
sour gas processing and is expected to add 5 million cubic feet per day. Sour gas contains a high
amount of hydrogen sulphide, which makes processing more costly. However, this type of gas
makes up the majority of the UAE’s natural gas.

Natural gas represents 99 per cent of Abu Dhabi’s power generation mix. Abu Dhabi Water and
Electricity Authority (Adwea) expects the emirate’s power consumption to rise by 11.3 per cent
each year, forcing Abu Dhabi to tap the more difficult gas.
The UAE is also looking to diversify its energy mix with the goal of generating 24 per cent of its
total power generation by clean energy projects by 2020. “We continue to draw a clear strategy in
energy, and we believe our economy is based on diversification,” the UAE Minister of Energy
Suhail Al Mazrouei said last week.
The Minister of Economy Sultan Al
Mansouri said that the country was
the front-runner for branching out
from the oil and gas sector. “The
UAE is the most diversified
economy in the Middle East,” Mr Al
Mansouri said.
Two major clean energy projects
are expected to feed electricity into
the grid in two years. The second
phase in the Mohamed bin Rashid
Al Maktoum Solar Park will
generate 100 megawatts of solar
photovoltaic (PV) power. Dubai
Electricity and Water Authority
(Dewa) issued the tender for the
second phase on November 20. Dewa expects the project to be completed in 2017.
“The Mohammed bin Rashid Al Maktoum Solar Park [will be] one of the largest renewable energy
projects in the region and demonstrates our commitment to achieve our vision to become a
sustainable world-class utility,” said Saeed Mohammed Al Tayer, the Dewa managing director and
chief executive.
The third project expected to increase power generation in three years’ time is Emirates Nuclear
Energy Corporation’s power plant in Barakah capable of generating 1.4 GW, which is located 300
kilometres west of Abu Dhabi. Enec said in September that more than 57 per cent of the first of
four reactors had been completed.
Enec expects the second unit to follow in
2018 and units three and four will come
online in 2019 and 2020, respectively.
The company said that the four reactors
would provide about 25 per cent of the
country’s electricity needs.

Qatar:Oryx GTL forum focuses on its 2015 shutdown
Gulf Times + NewBase
In line with Oryx GTL’s commitment to sustainable development and actively pursuing stakeholder
satisfaction, the company’s Contracts and Materials Department held its ‘3rd Annual
Contractors/Suppliers Forum’ at the Sharq Village recently.
The forum was chaired by Oryx
GTL’s chief commercial officer
(CCO), Mohamed Sharif Ibrahim
al-Mushiri, supported by
Mohamed Faraj Ezran, contracts
manager and Johannes Van Der
Merwe, acting/materials manager.
The forum was also attended by
the executive management,
managers and staff members of
Oryx GTL’s Commercial Group as
well as the company’s contractors
and suppliers.
The theme of the forum was
‘Connect, Exchange, Cooperate’,
which was aimed at facilitating
interaction between Oryx GTL and
the participating companies towards improvement in compliance, practices and business
relationship, with emphasis on the 2015 shutdown. Al-Mushiri expressed his happiness and
gratitude to all attendees for their presence.
In keeping with Oryx GTL’s values and safety culture, the first presentation by Gideon Jankowitz,
security supervisor was titled ‘HSE Safety Moment’ on ‘Vehicle Access to Site.’
Other presenters during this event were Dana al-Dafaa, contracts specialist, who presented ‘Vision
and Values Moment’ on ‘Create a Winning Team’; Philip Thorpe-Willett, head (contracts) provided
an update on outstanding actions from last year’s forum; Gerardus Toet, process optimisation
specialist, spoke on ‘Business Continuity’ and Lakhdar Barka, head (contract services) presented
‘2015 shutdown cost control’.
Nawaf al-Amri, materials buyer, provided an input on procurement and warehouse issues with
regards to 2015 shutdown and Michael Lineses, contracts specialist, provided a presentation on
this year’s improvements.
Yasser Habib, head (procurement) presented answers to questions raised in advance by the
attendees and thereafter the master of ceremony. Ahmad Alsheeb hosted the Q&A open session,
where all attendees had the opportunity to freely express their views, ask questions, discuss
issues and areas of improvement as well as share their expectations on various business issues
and practices such as clarity of specifications, bid submission and evaluation, amongst others.

Morocco: PetroMaroc seeks industry partner to develop Sidi Moktar
Source: PetroMaroc
Dundee Capital Markets to help evaluate strategic and financial alternatives PetroMaroc
Corp is pursuing a series of strategic and financial alternatives with the objective of maximising
shareholder value following the independent assessment of prospective resource in
the Kechoula structure on the Sidi Moktar Exploration Licence in Morocco.
'We will be pursuing all available options
to maximize shareholder value from our
promising Kechoula structure,' said Tom
Feuchtwanger, PetroMaroc’s President
and CEO. 'Our recently updated
independent evaluation of the
undiscovered petroleum initially-in-place
and the prospective resource has defined
the strong prospectivity and a path
towards the commercial development of
Kechoula'.
The independent evaluation by GLJ
Petroleum Consultants confirmed
PetroMaroc’s geological and geophysical
model for the Lower Liassic reservoir of
the Kechoula structure. The report also
confirmed (81 percent probability) that the
Lower Liassic clastic reservoir is filled to
spill point, and reported a prospective
resource of gross lease unrisked
undiscovered petroleum initially-in-place
of 394 billion cubic feet (mean estimate).
Petrophysical analyses of the sidewall
cores collected during the drilling of
the Kamar well reported visual porosities
of 13 to 20 percent in the Lower Liassic reservoir interval.
Dundee Capital Markets has been appointed as financial adviser to evaluate alternatives that
may include, but are not limited to, farm-out of Sidi Moktar, sale of the Company, merger or other
business combination, recapitalization, sale of all or a portion of the Company’s assets, or any
combination thereof. Dundee will also evaluate alternatives for PetroMaroc to continue its
business plan, among other alternatives.
Parties who execute a confidentiality agreement will have access to an online and physical data
room, as well as management and technical presentations. All interested parties should direct
enquiries to Dundee.
PetroMaroc recently initiated a non-brokered private placement to raise proceeds of a minimum
of Cdn $3 million and a maximum of Cdn $6 million to support near-term efforts while the search
for an industry partner is underway. PetroMaroc closed the first tranche of the Private Placement
raising Cdn $3 million on November 4. The Company anticipates to close the second tranche of
the Private Placement in December. The Private Placement is subject to the final approval of the
TSX Venture Exchange.

Statoil to operate giant Johan Sverdrup field
Source – StatOil
Statoil will become operator for all phases of the massive Johan Sverdrup field in the North Sea,
offshore Norway. The decision has been made by the partners in the field, Statoil has announced.
Statoil said that the decision will be added in the Unit Operating Agreement (UOA), which is
planned to be submitted to the authorities in February 2015 together with the Plan for
Development and Operation (PDO).
“Statoil will cooperate closely with its partners in order to secure the best possible utilization of the
resources on Johan Sverdrup. The goal is to achieve a recovery factor of at least 70% from the
field,” the company said in a press release.
The field development plan includes a field center that will carry out the most important functions
while also allowing for the subsequent connection of various installations during the
development’s different phases. This integrated solution will ensure efficient field development
and operation.
“Statoil’s plan is to establish a production organisation for the field in Stavanger, while at the same
time drawing upon the considerable expertise of its partners and the supplier industry. Johan
Sverdrup will represent a powerhouse of value creation and employment in Norway for many
decades to come,” Statoil added.
Johan Sverdrup is one of the largest oil discoveries ever made in the history of the Norwegian
continental shelf, probably among the top five oil fields. Partners in the field, which encompasses
three production licences are Statoil, Lundin Petroleum, Maersk Oil, Petoro and Det norske
oljeselskap.
The resource estimate for the entire field is between 1.8 and 2.9 billion barrels of oil equivalent.
On plateau Johan Sverdrup will account for 25% of the total oil production in Norway. Production
start is scheduled for the end of 2019.

U.S. gasoline prices this Thanksgiving are the lowest since 2009
Source: U.S. Energy Information Administration,
U.S. retail regular-grade gasoline prices continue to decline, averaging $2.82 per gallon (gal) as of
November 24. This average is 47 cents lower than a year ago, and the lowest price heading into a
Thanksgiving holiday since 2009.
Traditionally, the Thanksgiving holiday is one of the most traveled times of the year in the United
States, and much of that travel is by car. AAA estimates that during this Thanksgiving holiday
weekend (November 26-30), 41.3 million people in the United States will travel more than 50 miles
from home by car.
This level of travel, 4.3% higher than the same time last year, is the highest number of travelers by
car for Thanksgiving in seven years and the third highest since AAA began publishing the data in
2000.
Gasoline prices across the country reflect differences in gasoline quality, taxes, and the
characteristics of regional market supply and demand balances. West Coast prices typically
exceed the U.S. average because of stricter fuel specifications in California and the region's
isolation from other domestic markets. Regional differences in gasoline prices are also attributable
to variations in state and local taxes and differences in regional supply costs.
Much of the decline in gasoline prices since mid-2014 is attributable to falling crude oil prices. The
combination of robust U.S. crude oil production growth, a return of Libyan production (despite
recent setbacks), weakening expectations for the global economy (particularly in China), and
seasonally low refinery demand has reduced oil prices.
North Sea Brent spot prices have fallen from a July monthly average of $112 per barrel (bbl) to a
November monthly average of $80/bbl (through November 24). The average U.S. retail regular-
grade gasoline price has fallen 88 cents/gal since the start of July.

EIA's November 2014 Short-Term Energy Outlook (STEO) projects the U.S. average retail price of
regular gasoline will continue to decline for the remainder of the year and will average $2.80/gal in
December.
The STEO forecast of annual average U.S. regular gasoline retail prices is $3.39/gal in 2014 and
$2.94/gal in 2015, well below the $3.51/gal price in 2013. However, as discussed in the STEO, the
current value of futures and options contracts implies a wide confidence interval for forecasts of
crude oil, which is the main determinant for gasoline prices.
Source: U.S. Energy Information Administration, Short-Term Energy Outlook
Note: Dollars per barrel calculated using conversion rate of 1 barrel = 42 gallons. WTI is West
Texas Intermediate

US: Cost cuts for unconventional oil, gas to have sweeping impact
Saudi gazette + NewBase
With research concluding up to 40 percent savings in operational costs for unconventional wells in
the United States, the Middle East must innovate their energy strategy to remain relevant,
according to Accenture’s new report titled
“Achieving high performance in unconventional operations, integrated planning, services, logistics
and materials management”. The report said oil and gas operators in the United States can
reduce the costs of constructing, drilling and completing unconventional wells, as well as the
overall time it takes to complete them, by up to 40 percent through better planning and
management of logistics, contractors and materials.
For particularly high performers, these could mean costs reductions of $1.3 million to $2.6 million,
on a $6.5 million well, and much more for the low performers. Operators can achieve these
savings by adopting a more integrated planning process, better management of service
contractors, and improved logistics and materials management for fresh and reused water and
installed equipment.
“Our global research team has found that operators of the Eagle Ford Shale model in the top
quartile spend about $6 million per well, some still struggle to deliver wells for twice that amount,”
said Omar Boulos, managing director, Accenture in the Middle East.
“To generate the maximum savings and efficiencies, operators need to carefully balance their
investments in technology, continuous improvement and people, and in the low-margin
environment of unconventionals, trade-offs will need to be made.

For example: Is investment in new rig technology a better choice than offering incentives to your
service provider to ensure consistency of crew?” Technological developments in unconventional
exploration in the United States could also have serious consequences for the downstream
industry in the Arabian Gulf.
“Historically speaking, the petrochemicals producers in the GCC countries have enjoyed access to
favorably priced feedstock, which has led to the emergence of a dynamic downstream industry,”
Boulos further said.
“The emergence of feedstock alternatives in the United States is leading analysts to forecast
much activity in the downstream sector in North America, particularly in the fertilizers market.
This could potentially affect the profit margins of the GCC petrochemicals sector which is an
export driven industry.” Accenture’s report covers several planning and management issues and
ways operators can improve performance, including:
• Integrated Planning – With hundreds or thousands of wells in a single field and production
forecasts largely driven by drilling new wells, the lack of an integrated planning approach in
unconventional operations can lead to missed production targets and capital overruns. To avoid
this, operators will need to apply planning tools, simplify planning schedules, break down
organizational silos and integrate service providers into the planning process.
• Logistics Management – At 5 million gallons and 1,000 truck movements per well, efficient
water use and movements continue to provide a competitive advantage in unconventional
operations.
But there’s also an opportunity to improve non-water movements, such as proppant and
aggregates. It’s critical to make the best use of rail, road and pipeline transport and select the
most optimal locations for permanent and temporary storage.
• Management of Drilling and Other Service Contractors – Unconventional development is
characterized by a large number of service providers and a large number of handovers on the
site.
Operators need to ensure better collaboration between these contractors and apply strict financial
controls and management to meet risk, commercial and operational requirements.
• Materials Management – Given the number of wells on a multi-well pad and 24-hour crews, an
unconventional operation requires a much higher volume of materials than a conventional one.
The management of these materials needs to be efficient and agile to ensure timely delivery, in
order to minimize downtime and avoid tying up working capital and racking up needless storage
expenses.
“Our research suggests that large independent operators are best positioned to implement these
improvements, as they tend to have a trade-off mind-set when it comes to investments in
technology, continuous improvement and people,” Boulo noted. “They know that you cannot invest
in all three all of the time as that would be too expensive,” he added.

Oil Price Drop Special Coverage
Oil and gas price collapse
Washington Post + NewBase
The news in the markets is dramatic: Crude oil prices dropped below $70 (Dh257) per barrel. This
continues a dramatic price decline for a commodity that in late June cost more than $100 per
barrel.
The shift has markedly lowered US gas prices (which are now well below $3 per gallon) and thus,
may be beefing up the US economy heading into the Christmas spending season, by putting
considerably more money in consumers’ wallets. But what’s driving this trend — which is quickly
becoming the single most important economic story of 2014?
1. Opec: First and most immediately, there’s the fact that the Organisation of Petroleum Exporting
Countries decided not to cut oil production at their meeting Thursday. This was Opec’s “most
important [meeting] in years,” the Post’s Steven Mufson reported on Tuesday, because it came
amid a pre-existing downtrend in prices, and everybody wanted to know if Opec would take any
action to halt the decline.
It didn’t — and crude oil prices immediately tanked.
But where did the broader and longer term downtrend come from? Three more answers:
2. Booming US and world oil production: Even as Opec kept production steady, it has been
growing elsewhere. The United States, most of all, has seen a major growth in oil production,
thanks to the shale oil revolution. The figures from the Energy Information Administration are truly
dramatic: Almost twice as many barrels a day of crude oil are being produced now in the US,
versus in 2005.
Production of oil has also been up in many other countries. Canada increased its total production
from just more than 3,300 barrels per day in 2009 to over 4,000 in 2013 and Russia increased
from 9,900 barrels per day in 2009 to 10,500 barrels per day over the same time period. Libya,
meanwhile, is bouncing back after production tanked in 2011 due to the country’s civil war.
In sum, there’s just more oil out there for people to buy, which is having a predictable effect on
prices, pushing them downward.
3. Slack demand in many regions including Japan and Europe: There’s also the fact that
while the U.S. has recovered steadily from the Great Recession, many other countries have not.
They’re struggling, and that is dampening oil demand.
In Europe, for instance, while total petroleum consumption averaged well over 14,000 barrels per
day in 2010 and 2011, it was less than 13,000 in the first quarter of this year, and not much higher
in the second quarter. There’s a similar story to be told about Japan, where demand is also
dropping, according to the Energy Information Administration.

4. Strides in vehicle fuel efficiency: In the US, we’re also using less fuel in our cars because
those cars are more efficient. The average fuel efficiency of a newly purchased light-duty
passenger vehicle in this country was 36 miles (58 kilometres) per gallon in 2013. Back in 1980, it
was 24.3 miles (39 kilometres) per gallon.
So in sum, the trend in oil prices is fundamentally due to that most basic of economic factors:
Supply and demand.
So what happens next? Does the trend continue, or is it possible we’ve already overshot and are
due for a reversal in oil prices? Observers can’t be sure but there are some reasons to think a
bounceback could be possible. And in the long term, overall fuel consumption is definitely
projected to increase, not decline, out towards 2040 — driven largely by developing nations.
Oil prices sink as struggle for global market clout heats up
WITH Venezuela leading the campaign for an output cut and most
others not in favor, fireworks at the OPEC Secretariat in Vienna,
during the five hour long ministerial last Thursday, seemed inevitable.
On one hand, there were some stressing on measures to ensure long-term market stability and on
the other there were few, apparently pressed by the immediate budgetary concerns, who were on
a lookout for immediate remedial measures.
By Wednesday evening, a day prior to the meeting, the writing was very much on the wall. An
output rollover appeared imminent. With a deal between Iran and P5+1 at
least deferred for the time being and a possible deluge from Tehran out of
reckoning for at least another six months, OPEC hawk Iran too appeared
getting close to the majority position.
The situation began to crystallize further when Russia, producing 10.5 million
bpd or 11 percent of global oil, opted out of a voluntary output restraint
regimen - despite some initial hints. At a meeting with Saudi Oil Minister Ali Al-Naimi and

officials from Venezuela and non-OPEC member Mexico prior to the OPEC moot, Russia’s most
influential oil official, state firm Rosneft’s head Igor Sechin, emerged with a surprise message -
Russia will not reduce output even if oil falls to $60 per barrel.
Sechin added that he expected low oil prices to do more damage to producing nations with higher
costs, in a clear reference to the US shale boom. Gulf Arab OPEC members also streamlined their
position, reaching a consensus ‘not to cut output’ at this moment. Naimi asserted the oil market
“will stabilize itself eventually.”
UAE Oil Minister Suhail bin Mohammed Al-Mazroui too added his voice to the chorus, saying
“market will fix itself ultimately.” Kuwait’s oil minister too was not much behind. “We have to live
either with $80 or with $60 or with $100,” Ali Saleh Al-Omair told reporters.
He then asserted “oversupply came from the evolution of the unconventional oil production ... I
think everyone needs to play a role in balancing the market, not OPEC unilaterally.”
And interestingly, Iran insisting until then on an output cut, too seemed to be getting close to the
dominant opinion within OPEC. Prior to the meeting, Iranian Oil Minister Bijan Namdar Zangeneh
indicated that he and Saudi Oil Minister Al-Naimi were “very close” in their positions.
“The most important thing for all of us is the unity and solidarity of OPEC, and in this situation I
believe we need to have the contribution of non-OPEC producers for managing the market,”
Zangeneh told reporters.
And thus despite the realization that the current output regimen was almost a million bpd more
than the call on its crude, a rollover was imminent. In a statement after the meeting, OPEC
asserted that the ministers “in the interest of restoring market equilibrium” had decided to maintain
its current production levels.
The battle royal to protect OPEC markets share has begun, screaming headlines said all around
immediately after. If OPEC were to cut exports without similar action by its competitors, it would
lose further market share, including to North American shale oil producers, Reuters said.
OPEC was no more ready to shoulder the entire output cut burden. Speaking to CNBC, Nigeria’s
Petroleum Minister and the newly elected OPEC president Diezani Alison-Madueke said non-
OPEC oil producers also need to “share the burden” of any future cut in production.
“In keeping the production target at 30 mbpd, OPEC is clearly signaling that it will no longer bear
the burden of market adjustment alone and this decision puts the onus on other producers,
especially US tight oil to adjust as well,” a note from Barclays Instant Insights said.
Russian intransigence on output cut was also noted. Neil Atkinson, the head of analysis at Lloyd’s
List Intelligence emphasized that Saudi Arabia was right to be patient in making a decision and
will use the next three months to put further pressure on non-OPEC producers—like Russia—to
come to an agreement on production.
OPEC in its communiqué said: “The Conference also noted, importantly, that, although world oil
demand is forecast to increase during the year 2015, this will, yet again, be offset by the projected
increase of 1.36 million bpd in non-OPEC supply.” And this was no more apparently acceptable to
OPEC ministers.

And with OPEC moving to protect its markets share, global media is buzzing; it is evoking
memories of 1986 oil price and market war. Then too, like the currently ongoing shale revolution,
oil output from Alaska’s North Slope and the North Sea came on line (combined production of
around 5-6 million barrels a day), and began chipping at OPEC’s market share.
The current scenario has some similarities. A Deutsche Bank report said
that around 40% of shale oil production in the United States next year,
would be unviable if the price of oil fell below $80 per barrel.
However, Maria van der Hoeven, executive director of the International
Energy Agency, is of the opinion that 82 percent of the American shale
oil firms had a break-even price of $60 or lower.
Javed Mian writing in Stray Reflections says: “The median North
American shale development needs an oil price of $57 to break even today, compared to $70 last
year according to research firm IHS.”
Analysts at Citibank recently said that the price of oil would have to fall below $50 a barrel for
completely halting shale oil production in the United States. Also, many shale oil companies would
continue to remain viable for an oil price of anywhere between $40 to $60 a barrel. Indeed no
single figure is available. Opinions though vary - and by far.
Dimension of the current moves on the global energy chessboard are simply too many and the
rumblings of it would be felt for long - one could now say with some certainty.
Opec refusal means weakest left behind
Bloomberg
Saudi Arabia and its Opec allies’ firm stand against cutting crude output to slow the plunge in oil
prices has set the energy world on a painful course that will leave the weakest behind, from
governments to US wildcatters.
A grand experiment has begun, one in which the group of producing nations - sometimes called
the central bank of oil - is leaving the market to decide who is strongest and how to cut as much
as 2mn bpd of surplus supply.

Oil patch executives including billionaire Harold Hamm have vowed to drill on, asserting they can
profit well below $70 a barrel, with output unlikely to fall for at least a year. Marginal producers in
less profitable US shale areas, as well as countries from Iran to Russia and operations from
Canada to Norway will see the knife sooner, according to analyses by Wells Fargo & Co, IHS Inc
and ITG Investment Research.
“We’re in a very nerve-wracking environment right now and will be for probably the next couple of
years,” Jamie Webster, senior director for global crude markets at IHS, said on Friday in a phone
interview. “This is a different game. This isn’t just about additional barrels, this is about barrels that
are going to keep coming and keep coming.”
Investors punished oil producers,
as Hamm’s Continental Resources
Inc fell 20%, the most in six years,
amid a swift plunge in crude to
below $70 for the first time since
2010. Exxon Mobil Corp declined
4.2% to close at $90.54 in New
York. Talisman Energy Inc, based
in Calgary, was down 2.7% on
Friday in Toronto after dropping
14% the day before.
A production cut by the 12-
member Organisation of
Petroleum Exporting Countries
would have been the quickest way
to tighten the world’s oil supplies and boost prices. In the US, output is expected either to remain
flat or rise by almost 1mn bpd next year, according to the Paris-based International Energy
Agency and ITG.
That is because only about 4% of shale production needs $80 or more to be profitable. Most
drilling in the Bakken formation, one of the main drivers of shale oil output, returns cash at or
below $42 a barrel, the IEA estimates.
ITG estimates it will take six months before lower prices slow production growth from US shale,
which is responsible for propelling the country’s production to the highest in more than three
decades.
Elsewhere, oil markets already have begun to pressure governments that rely on higher prices to
finance their budgets, fuel subsidies to citizens and expand drilling. Venezuela’s oil income has
fallen by 35%, President Nicolas Maduro said on state television November 19.
Nigeria increased interest rates for the first time in three years on November 26 and devalued its
currency. The government is planning to cut spending by 6% next year, Finance Minister Ngozi
Okonjo-Iweala said on November 16. Both Nigeria and Venezuela are part of Opec.
Several countries within Opec such as Iran, Iraq, Nigeria and Venezuela, as well as non-Opec
states such as Russia and Norway, will probably have to cut production with lower oil prices in
2015 and beyond, Roger Read, an analyst at Wells Fargo, said on Friday in a note to investors.

The probability of a recession in Russia in the next 12 months rose to 75%, according to a survey
of economists compiled by Bloomberg - the highest since the first poll two years ago. Russia
receives about half of its budget revenue from oil and gas taxes.
In Canada, the massive investment needed to exploit oil sands has generated momentum that will
take time to stop. Output will rise from money already spent and projects that are too expensive to
halt, said Jennifer Stevenson, who helps oversee C$5.5bn ($4.8bn) at Dynamic Funds in Calgary.
Shale producers have a closer hand on the throttle, she said. Because output from new wells
declines rapidly, a cutback in drilling by cash-strapped companies can slow production in months,
not years. Cash flow for EOG Resources Inc would fall 24% next year to $28.96 per equivalent
barrel of oil with US crude at $65 a barrel, versus $85, according Peters & Co estimates.
“Any of these high growth companies are going to have less cash flow and less growth so I think
you’ll see the overall growth rate of North American production slow down,” Stevenson said.
“What I don’t think you’ll see is the overall production actually decrease.”
With a sustained price drop to $60 a barrel, North American shale drilling would be especially
challenged in emerging fields such as some in Ohio and Louisiana, where costs are at the highest
early in development, according to Citigroup and ITG.
“It’s going to be very producer-specific,” said Judith Dwarkin, chief energy economist at ITG in
Calgary. “Companies have to revise their budgets, then you see the laying down of rigs, then you
see the fewer wells being drilled, then you see the natural decline rates starting to have more of
an effect.”
Drilling in Western Canada may drop by 15% in 2015, according to a report on Friday by Patricia
Mohr, an economist at Bank of Nova Scotia in Toronto.
Among the worst hit shale producers will be smaller operators that rely heavily on debt and are
focused on newer, higher-cost areas.
Goodrich Petroleum Corp is one example. With a market capitalisation of just $269mn, the upstart
producer is developing a prospect in Louisiana and Mississippi that one rival called possibly one
of the last great opportunities in North America. But drillers in the Tuscaloosa Marine Shale need
oil prices at about $79.52 a barrel, according to Bloomberg New Energy Finance.

Lower oil prices changing risk profile in EMs
The Peninsula + NewBase
The recent drop in oil prices is changing the risk profile of Emerging Markets (EMs). Significant
adjustments to global financial markets in the second half of 2014 include a large drop in
commodity prices, the end of quantitative easing (QE) in the US, and a stronger US dollar, the
QNB Group said. These developments, particularly the drop in oil prices, have led to a divergence
in EM performance and risks going forward. At this juncture, the most exposed countries are
Russia and Ukraine, followed by other commodity producers like Brazil and South Africa.
We have previously identified the EMs most at risk of a balance of payments crisis (see our
Economic Commentary dated June 6, 2014). This analysis focused on the fragile five (Brazil,
India, Indonesia, South Africa and Turkey) EMs that were most severely impacted by the capital
outflows following the announcement in mid-2013 of the QE tapering by the US Federal Reserve
(Fed). We now have added Russia and Ukraine to our list of EMs that face a material risk of a
crisis (owing to the fallout between the two countries as well as the recent drop in oil prices) to
make up the so-called Suspect Seven.

Overall, the second half of 2014 has resulted in a significant EM differentiation between those
markets that have been able to take the necessary measures to reduce their current account
deficits and stabilize their currencies (India and Indonesia) and those that are still struggling to
contain the loss of confidence in their economies (Brazil, Russia, Ukraine and to a lesser extent
South Africa). Much of the loss of confidence in the latter group has been driven by lower global
commodity prices, including oil.
The improvement in financial market sentiment towards the ‘Suspect Seven’ has occurred despite
a steady downward revision in the outlook for these economies, with the main exception of India.
According to Bloomberg consensus, real GDP growth is now expected to be 5.4 percent in 2014
up from 4.7 percent expected in June. Indonesia is the only other Suspect Seven expected to
grow by over 5 percent in 2014.
Lower oil prices have been a key differentiator of EM performance during the second half of 2014.
Brent oil prices peaked in mid-June at $115 per barrel. Since then prices have fallen over 30
percent to around $80 currently. Falling oil prices have helped improve external balances in India
and Indonesia and their governments have also taken the opportunity presented by lower oil
prices to increase fuel prices and reduce their subsidy bills.
Indian Prime Minister Narendra Modi announced in mid-October that the government would stop
fixing diesel prices, eliminating half of total fuel subsidies, which cost the government around 9.4
percent of the budget last year. Indonesian President Joko Widodo announced in mid-November a
30 percent increase in fuel prices, which follows a 33 percent increase in June 2013. Fuel
subsidies are expected to reach around 19 percent of the Indonesian budget this year.
Russia has been the hardest hit by falling oil prices — the exchange rate has weakened 34.9
percent since the end of June as falling oil prices have exacerbated weaknesses relating to
international sections associated with tensions in Ukraine.
Ukraine itself is in a particularly dire situation. The economy is now expected to contract by 7
percent this year. Sovereign default was narrowly averted in May with an agreement for external
support from the IMF and other donors totaling $27bn. International reserves fell to just $12.6bn
from $16.3bn at end-September. The central bank gave up on efforts to defend the currency in
early October and is now running short of reserves. Without continued external support, Ukraine is
likely to experience a sovereign default.
In Brazil, falling oil and commodity prices have also added to concerns about political uncertainty

that stem from the October presidential elections and delays to appointing a new government.
This has led to a sharp depreciation of the Brazilian real of 13.9 percent since the end of June
2014.
The outlook for South Africa has deteriorated slightly during the second half of the year as the
economy is predominantly reliant on commodities. Falling commodity prices have led to a
downward revision in consensus real GDP growth forecasts from 1.9 percent in June to 1.5
percent currently.
The small weakening of Turkey’s currency since June has mainly been driven by a deterioration in
the security situation in neighbouring countries. Turkey faces some major challenges with a
current account deficit expected to be over 5 percent this year, although, as a net oil importer, the
drop in oil prices should help.
Another important factor that has supported EMs is further unexpected monetary easing in China
and Japan, which has eased global liquidity conditions. Previously, financial markets had been
concerned about the ending of QE in the US in October. However, the People’s Bank of China
unexpectedly cut lending and deposit rates on November 24. Additionally, the Bank of Japan
surprised markets by expanding its QE programme at the end of October with much of the
additional liquidity expected to flow to EMs in search of higher yields.
Overall, recent developments in global financial markets have helped stabilise some of the fragile
EMs that were previously thought to be at risk. However, recent developments, including lower oil
and commodity prices, have been less positive for commodity exporting countries, particularly
Russia and Brazil, which are suffering as a result. Political tensions in Ukraine are pushing the
country close to the brink. If Ukraine goes down, contagion could further destabilises Russia.

Your Guide to Energy events in your area

Your partner in Energy Services
NewBase energy news is produced daily (Sunday to Thursday) and
sponsored by Hawk Energy Service – Dubai, UAE.
For additional free subscription emails please contact Hawk Energy
Khaled Malallah Al Awadi,
Energy Consultant
MSc. & BSc. Mechanical Engineering (HON), USA
ASME member since 1995
Emarat member since 1990
Mobile : +97150-4822502
khdmohd@hawkenergy.net
khdmohd@hotmail.com
Khaled Al Awadi is a UAE National with a total of 25 years of experience in
the Oil & Gas sector. Currently working as Technical Affairs Specialist for
Emirates General Petroleum Corp. “Emarat“ with external voluntary Energy
consultation for the GCC area via Hawk Energy Service as a UAE
operations base , Most of the experience were spent as the Gas Operations
Manager in Emarat , responsible for Emarat Gas Pipeline Network Facility &
gas compressor stations . Through the years , he has developed great
experiences in the designing & constructing of gas pipelines, gas metering & regulating stations
and in the engineering of supply routes. Many years were spent drafting, & compiling gas
transportation , operation & maintenance agreements along with many MOUs for the local
authorities. He has become a reference for many of the Oil & Gas Conferences held in the UAE
and Energy program broadcasted internationally , via GCC leading satellite Channels.
NewBase : For discussion or further details on the news above you may contact us on +971504822502 , Dubai , UAE
NewBase 30 November 2014 K. Al Awadi

New base 489 special 30 november 2014

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