New base 783 special 09 februaury 2016

Copyright © 2015 NewBase www.hawkenergy.net Edited by Khaled Al Awadi – Energy Consultant All rights reserved. No part of this publication may be reproduced, redistributed,
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NewBase 09 February 2016 - Issue No. 783 Edited & Produced by: Khaled Al Awadi
NewBase For discussion or further details on the news below you may contact us on +971504822502, Dubai, UAE
UAE: Dewa to tender third phase of solar park
Utility CEO says contract for adding 800 MW of capacity will be awarded in June
Reuters + Gulf News
The Dubai Electricity and Water Authority will launch a tender to build the third phase of the
Shaikh Mohammad Bin Rashid Al Maktoum Solar Park in six weeks, its chief executive said on
Monday.
“Within a short period, we will open the tender, within a month and a half,” Saeed Mohammad Al
Tayer, Managing Director and Chief Executive Officer of Dubai Electricity and Water Authority,
told Reuters on the sidelines of a conference.
“The award of this contract will be this year, according to the programme, in June — 800
megawatts will be awarded.”
Dewa said in September it would start accepting expressions of interest for the plant. Al Tayer did
not give a figure for the cost of the project. Dubai doubled the capacity of the second phase of the
solar park from 100 MW to 200 MW after receiving the lowest-ever recorded cost for solar power
in a tender won by Saudi Arabia’s ACWA Power and Spain’s TSK. The emirate’s strategic plan
envisions 7 per cent of power generation from renewables by 2020 and 15 per cent by 2030.

Morocco: Sound Energy announces option to acquire interest in
the Meridja permit, onshore Morocco.. Source: Sound Energy
Sound Energy, the Mediterranean and European focused upstream gas company, has signed a
binding agreement with Oil & Gas Investment Fund ('OGIF') whereby OGIF has granted Sound
Energy an option to acquire a 55% interest in the Meridja permit, onshore Morocco.
Meridja is adjacent to Sound Energy's existing Tendrara licence and is a highly prospective
9,000 Km2 area with the same fundamental geology as Tendrara, where Sound Energy expects
to drill its first well shortly. OGIF currently holds a 75% interest in a reconnaissance permit over
the Meridja area, with the remaining 25% interest held by Morocco's Office National des
Hydrocarbures des Mines ('ONHYM').
OGIF has granted
the Option to
Sound Energy,
under which
Sound Energy is
able to acquire
(subject to
regulatory and
other approvals) a
55% interest in
and operatorship
of the Meridja
exploration
permits, once
awarded.
As consideration
for the Option,
Sound Energy will
pay OGIF US$100,000 and will conduct and fund early stage commitments under the
Reconnaissance Permit up to a maximum of US$200,000. On exercise of the Option Sound
Energy would pay OGIF a further US$150,000 and would carry OGIF and ONHYM for costs up
to the end of a first Meridja exploration well.
The Reconnaissance Permit, which was recently successfully extended by OGIF, has an expiry
date of 1 August 2016.
James Parsons, Sound Energy's Chief Executive Officer commented:
'Following our entry into Morocco last year, we have moved quickly to build our regional position
further in a highly prospective area. The Option secures exclusive access to a key permit
adjacent to Sound Energy's existing Tendrara licence and will enable us to increase our upside
potential significantly should the first well at Tendrara be as successful as we hope. The
transaction further demonstrates our strong partnership with OGIF and further consolidates our
position as a leading onshore operator in Morocco.'

Morocco: Qatar Petroleum and Chevron announce agreement
for exploration of deepwater offshore blocks Source: Qatar Petroleum
Qatar Petroleum has reached an agreement with Chevron Morocco Exploration, a subsidiary
ofChevron Corp, to acquire a 30% participating interest from Chevron’s 75% share in three
deep-water offshore leases in the Kingdom of Morocco.
Under the agreement, which was approved by the Moroccan government, Qatar Petroleum will
acquire the 30% interest in the deep-water leases, while Chevron will retain a 45% interest and
remains the operator and Morocco's Office National Des Hydrocarbures Et Des Mines will
continue to have a 25% interest. The three offshore areas are Cap Rhir Deep, Cap Cantin
Deepand Cap Walidia Deep.
Saad Sherida Al-Kaabi, President and CEO of Qatar Petroleum, expressed pleasure at the
finalization of the agreement, which he described as 'an important step towards building a
mutually beneficial relationship with Chevron with particular emphasis on international upstream
activities. It is no coincidence that Qatar Petroleum’s international presence is now extended to
Morocco, a country which Qatar enjoys speci al relations with,' he added.
Ali Moshiri, President of Chevron Africa and Latin America Exploration and Production said 'The
agreement is a milestone in both companies’ efforts to maximize the value of exploration and
production assets through long-term relationships. We are pleased to partner with Qatar
Petroleum in offshore Morocco and are looking forward to use our joint capabilities in this exciting
sub-salt play for the benefit of Morocco'.
The three offshore lease areas are located between 100-200 kms west and northwest of the
Morocco city of Agadir. They encompass approx. 29,200 sq kms with average water depths
ranging from 100 meters to 4,500 meters.

Morocco: Circle Oil Inks MoU Regarding Gas Supply to SBS Porcher
Circle Oil has announced that it, together with its partner Office National des Hydrocarbures et des
Mines (ONHYM), has signed a memorandum of understanding (MOU) with a potential new gas
customer in Morocco, SBS Porcher.
The memorandum forms the basis for Circle to sell the gas discovered during the successful
2014/15 Sebou drilling campaign and all parties expect to sign binding documentation in the
coming months, Circle Oil said in a press note published Monday.
As part of this arrangement, a new pipeline extension would be constructed linking the existing
Circle-owned pipeline in the northern Kenitra region to the Porcher factory in the central Kenitra area.
As per the MoU, Porcher would pay for (and own) the required pipeline extension of approx. 15-18
km (estimated cost of $2.5m) to central Kenitra, with construction estimated to start in May 2016
and first gas anticipated to flow during Q4 2016. Estimated gross offtake volume would be 10,000
cubic metres per day (approx. 0.35mmcf/d) with a price of MAD 4.25/cubic metre ($12/mcf). The
gas price would be fixed with no linkage to oil prices. The contract duration is 5 years.
This new contract when signed, will result in Circle achieving demonstrably higher gas prices, the
company stated, adding that it also enables Circle to access a potential new customer base in
central Kenitra.

Senegal: FAR reports increase in contingent resources at the
SNE oil field, offshore Senegal ..Source: FAR Ltd
Independent Resources Report completed by RISC for FAR’s SNE oil discovery, offshore
Senegal.
1. SNE oil field contingent resources (100% basis, recoverable) have been upgraded by RISC to
240 million barrels of oil ('mmbbls') 1C, 468 mmbbls 2C, 940 mmbbls 3C.
2. RISC’s SNE oil field contingent resource 2C of 468 mmbbls (70 mmbbls net to FAR)
represents a 42% increase to FAR’s previous estimate of 330mmbbls (50 mmbbls net to
FAR).
3. The SNE oil field Minimum Economic Field Size (“MEFS”) is estimated by FAR to be approx.
200mmbbls.
4. RISC will update its independent assessment following results from the ongoing SNE three
well appraisal progam.
5. SNE-3 appraisal well has been drilled to total depth, coring and wireline logging has now
been completed and operations are currently preparing for drill stem testing.
FAR Ltd commissioned RISC to prepare an Independent Resources Report for FAR’s SNE oil
field offshore Senegal. The report was prepared as at December 2015 incorporating recent
data available from wells SNE-1 and FAN-1 and reprocessed 3D seismic. The SNE contingent
resources set out in RISC’s Independent Resource Report represent a material increase to the
estimates previously reported by FAR in late 2014 (Refer: FAR ASX announcement 10
November 2014) with the SNE field 2C contingent resource increasing by 42% to 468 mmbbls
(100% basis, recoverable).
RISC reviewed and modified a probabilistic resource evaluation carried out by FAR in
accordance with industry standard SPE-PRMS definitions. Table 1 below sets out the SNE field
oil contingent resource estimates included in RISC’s report.
• Gross are 100% of the resources attributable to the licence
• Net attributable are reported on the basis of FAR’s current working interest share of 15%.
Petrosen has an option to increase its working interest through the exploitation phase to
13.7%
• The contingent estimates are not adjusted to reflect the Production Sharing Contract
entitlement on net economic interest basis
The estimation of Stock Tank Oil Initially in Place used 3D seismic data covering the field and
wireline log data from SNE-1. The recovery estimates have been evaluated using analytical

methods. The volumes of individual zones have been aggregated probabilistically taking account
of dependency between input property distributions. FAR has requested RISC to update its
independent assessment of SNE contingent resources follow ing results from each of the wells in
the ongoing three well SNE appraisal progam.
FAR announced the successful results from SNE-2, the first well of this appraisal program well,
in early January (Refer: FAR ASX announcement 4 January 2016). The second SNE appraisal
well (SNE3) is currently undergoing preparations for a drill stem testing program following the
successful drilling, coring and wireline logging of the well. SNE-3 has been drilled approx. 3km
south of SNE-1 at a location designed to evaluate the mid reservoir and upper “hetrolithic”
reservoir sections. This well will be followed by BEL-1, to be drilled into the Bellatrix Prospect and
evauate the Buried Hill exploration play as well as being deepened to appraise the northern part
of the SNE oil field.
RISC’s Independent Resource Report notes that the SNE field contingent resource estimates
presented in its report have not been updated to reflect the results of the SNE-2 appraisal well or
any other changes since December 2015, and that new data may materially impact these
contingent resource estimates. The SNE discovery is at a very early stage of appraisal and will
require significant further drilling, testing and studies before any commercial development
scheme could be defined.

India:Kochi SmartCity power plant inaugurated
Dubai Holding is an 84% shareholder in the project, the first phase of which
will open on February 20
By Gulf News - Chiranjib Sengupta, Hub Editor
The first power plant at Kochi SmartCity with a capacity of 11KV and an investment of Rs90
million (Dh4.86 million) was inaugurated on Sunday in order to provide immediate power supply to
the first phase of the ambitious IT project once it begins operations.
The first phase of the SmartCity project in the south Indian state of Kerala, in which Dubai Holding
is an 84 per cent shareholder through Tecom Investments, is scheduled for official inauguration on
February 20. The other 16 per cent is held by the government of Kerala. The project showcases
yet another successful example of close collaboration between UAE and Indian governments and
businesses.
“This is an independent set-up and we are also a separate electric licencee. So for all the
companies setting up business here, we can provide power connections directly without any
delay,” said Dr Baju George, Managing Director of SmartCity Kochi, following the inauguration.
“And we can also purchase power from anywhere in India by paying a network wheeling charges.
So companies here do not need to worry about the abundance of electricity, they can function
very effectively with our 24x7 power connectivity,” he said.
SmartCity Kochi is an IT Special Economic Zone with an envisioned built-up area of more than 8
million square feet, and is expected to create more than 80,000 direct job opportunities once all
the shifts are fully functional.

Third India- Australia Energy Security Dialogue Begins 8th – 11th Feb-16
India and Australia would look to discuss, among other issues, business cooperation in coal bed
methane and LNG production and trade, during the 3rd
India – Australia Energy Security Dialogue
to be held from 8th to 11th February 2016 at Australia. Piyush Goyal, Indian;s Minister of State for
Power, Coal and New & Renewable Energy will co-chair the Dialogue.
The coal sector of India envisages doubling its production in next five years. In this context, areas
such as CBM and coal mine methane development and underground coal gasification (UCG)
have been proposed for deliberations, the government said in a statement.
“Government of India has recently put in place a policy for development of underground coal
gasification and ministry of coal is likely to come up with some coal blocks for offer for
development of the resource. The Australian companies can look forward for participation in this
area.
There is ample scope for
the Australian mining
companies in participating
in the tenders for
development of different
coal blocks offered to
various public sector
companies in the recent
past. Coal India Limited is
embarking on
development of
CBM/CMM from their
leasehold areas where
Australian companies can
look forward for
participation for developing CBM resource,” the government said.During the energy dialogue,
India will share its perspective on upcoming opportunities for trade of LNG between India-
Australia. Policy collaboration on issues pertaining to LNG trade will also be discussed. A
Roundtable discussion on LNG trade, chaired by Goyal, will take place in Brisbane on 8th
February. During the Roundtable Indian participants will share their perspective on “growth of
natural gas and outlook of energy consumption in India” and the Australian side will share
their perspective on “Upstream development initiatives for facilitating business opportunities for
LNG production and trade”.
India’s Petronet LNG Ltd. has a 20-year contract with Gorgon gas to source 1.44 MMT of gas
annually. This will be supplied to IOCL, BPCL and HPCL for further distribution. The supplies are
expected to begin by November this year.
The India – Australia Energy Security Dialogue was established following the visit of then
Australian Prime Minister Julia Gillard to India in October, 2012. The Dialogue was
institutionalized to discuss areas of mutual interest in energy security and key issues in India and
Australia's energy markets, as well as regional and globe trends, and developments in both
countries. Two meetings of the Energy Security Dialogue were held in New Delhi and Brisbane in
2013 and 2014 respectively.

NewBase 09 February 2016 Khaled Al Awadi
NewBase For discussion or further details on the news below you may contact us on +971504822502 , Dubai , UAE
Oil prices jump 2% , shrug off equity slump, glut concerns
Reuters + NewBase
Crude oil prices jumped as much as 2 percent on Tuesday, shrugging off big drops in Japan's
stock market and eroding some of the previous session's losses that were driven by festering
concerns about global oversupply.
U.S. crude was up 49 cents at $30.18 a barrel at 0259 GMT, after rising as far as $30.30. The
contract fell about 4 percent on Monday, finishing at $29.69. Global crude benchmark Brent was
up 35 cents at $33.23 a barrel. It settled the previous session down $1.18 at $33.88.
Prices on Monday were hit by a drop in U.S. equity markets amid persistent fears about the global
economic slowdown. But on Tuesday, oil market traders ignored a 5-percent drop in Japan's
Nikkei . Many Asian markets are closed for Lunar New Year holidays.
"Once again we have got a weaker U.S. dollar and I suspect that that's where the bulk of the
support is coming from," said Michael McCarthy, chief market strategist at CMC Markets in
Sydney.
The U.S. dollar fell against the Japanese yen =JPY as sentiment towards most risk assets turned
bearish amid concerns about banking stability.
Oil price special
coverage

A declining dollar makes oil prices cheaper because most trade is denominated in the greenback,
potentially spurring demand. Still, the glut in world oil markets is unlikely to abate soon, with a
Reuters survey showing U.S. crude stocks likely rose by 3.9 million barrels in the week ended
Feb. 5.
Industry group American Petroleum Institute on Tuesday releases its weekly inventory reports
"The fundamentals haven't shifted. The market remains in surplus and while that's the case, it is
very difficult for prices to sustain any gains," McCarthy said. There is also little sign of any
coordination among big producers outside the United States after weekend talks between OPEC
members Saudi Arabia and Venezuela on possible coordination yielded little.
That dims prospects of any initiative on curbing supply to boost prices including producers like
Russia, analysts say. "Hopes of a coordinated supply cut from OPEC and non-OPEC members
continue to fade," ANZ said in a research note on Tuesday.
World's Largest Energy Trader Sees a Decade of Low Oil Prices
Bloomberg - Javier Blas javierblas2
Oil prices will stay low for as long as 10 years as Chinese economic growth slows and the U.S.
shale industry acts as a cap on any rally, according to the world’s largest independent oil-trading
house.
"It’s hard to see a dramatic price increase," Vitol Group BV
Chief Executive Officer Ian Taylor told Bloomberg in an
interview, saying prices were likely to bounce around a band
with a mid-point of $50 a barrel for the next decade.
"We really do imagine a band, and that band would probably
naturally see a $40 to $60 type of band," he said. "I can see
that band lasting for five to ten years. I think it’s fundamentally
different."
The lower boundary would imply little price recovery from
where Brent crude, the global price benchmark, trades at
about $35 a barrel. The upper limit would put prices back to
the level of July 2015, when the oil industry was already taking
measures to weather the crisis.
The forecast, made as the oil trading community’s annual IP
Week gathering starts in London on Monday, would mean oil-
rich countries and the energy industry would face the longest
stretch of low prices since the the 1986-1999 period, when crude mostly traded between $10 and
$20 a barrel.

Vitol trades more than five million barrels a day of crude and refined products -- enough to cover
the needs of Germany, France and Spain together -- and its views are closely followed in the oil
industry.
Taylor, a 59-year-old trader-cum-executive who started his career at Royal Dutch Shell Plc in the
late 1970s, said he was unsure whether prices have already bottomed out, as supply continued to
out-pace demand, leading to ever higher global stockpiles. However, he said that prices were
likely to recover somewhat in the second half of the year, toward $45 to $50 a barrel.
For the foreseeable future, Taylor doubts the oil market would ever see the triple-digit prices that
fattened the sovereign wealth funds of Middle East countries and propelled the valuations of
companies such as Exxon Mobil Corp. and BP Plc.
"You have to believe that there is a possibility that you will not necessarily go back above $100,
you know, ever," he said.
The problem is that "there is so much more supply" while the global economy is more efficient in
consuming crude. On top of that, Iran is returning to the market and growth in emerging markets,
the biggest engine of oil demand, is slowing.
"China has changed," he said.
Oil prices plunged after the Organization of Petroleum Exporting Countries in November 2014
diverged from its traditional policy of adjusting supply to manage prices, announcing it would
maintain output to defend its position in the market. The group formally dropped any production

limits in December, boosting output and intensifying a price war against higher-cost producers
including U.S. shale operations, the North Sea, Canada’s tar sands and deep-water discoveries in
Brazil and Angola.
Taylor said there could be an agreement between OPEC and non-OPEC countries like Russia to
cut production. "It’s probably slightly against, 60-40 against, but it’s a real possibility," he said,
While the price slump has hurt oil producers, independent traders such as Vitol and its
competitors Trafigura Group Pte, Glencore Plc, Gunvor Group Ltd, Castleton Commodities
International LLC and Mercuria Energy Group Ltd. are profiting from the increase in volatility.
These companies also benefit from a market structure called contango -- where forward prices are
higher than current costs. This allows traders to buy oil, store it in tanks and use derivatives to
lock in a higher selling price for a later date.
Taylor said that Vitol, which celebrates its 50th anniversary this year and its owned by its
employees, would report net income in 2015 above the $1.35 billion it earned in 2014. However,
he said the company wouldn’t match the record of nearly $2.3 billion of 2009. Taylor said that the
company, which doesn’t publicly release its profit, planned to take write-downs in its exploration
and production business and make provisions against customers defaulting on contracts. The
company, formally based in Rotterdam, has its major trading floors in London, Geneva, Singapore
and Houston.

NewBase Special Coverage
News Agencies News Release 09 February 2016
Oil Drillers Exposed in Three-Way Hedges as Crude Dips Below $30
Bloomberg - Asjylyn Loder
Oil at $30 a barrel is blowing a hole in the insurance that U.S. shale drillers bought to protect
themselves against a crash.
Companies including Marathon Oil Corp., Noble Energy Inc., Callon Petroleum Inc., Pioneer
Natural Resources Co., Rex Energy Corp. and Bonanza Creek Energy Inc. used a strategy known
as a three-way collar that doesn’t guarantee a minimum price if oil falls below a certain level,
company records show. While three-ways can be cheaper than other hedges, they leave drillers
exposed to sharp declines.
"At the time people hedged, they did it
without thinking that oil would go to $28,"
said Thomas Finlon, director of Energy
Analytics Group LLC in Jupiter, Florida.
"They didn’t have a realistic view about
whether the market would crumble or not."
The three-way hedges risk worsening a
cash shortfall for companies trying to
survive the worst oil crash in 30 years. The
insurance is all the more important after oil
plummeted 43 percent in the past year to
$26 a barrel in January, exacerbating the
pressure on debt-burdened producers.
"In 2015, everyone was given a hall pass and had a little protection from hedges," said Irene
Haas, an analyst with Wunderlich Securities. "But as we roll into 2016, the hedges aren’t as
attractively priced anymore and the hedges aren’t going to exactly bail you out."
Shale Boom
The U.S. shale boom was built on high oil prices and low-cost financing, which enabled drillers to
spend more than they earned while making up the difference with debt. With oil at a 12-year-low,
financing is much harder to come by. Locking in a minimum price for crude reassures investors
and lenders that companies will have the cash to pay their debts.
Joseph Gatto, Jr., Callon’s chief financial officer, told investors at a conference in December that
the company had hedged about 4,000 barrels a day in 2016, or 40 percent of its projected output,
at a price of $56 a barrel.
About half of those contracts are worth significantly less at $30 a barrel because Callon employed
three-ways, Securities & Exchange Commission records show. While the company is guaranteed

$58.23 for 364,000 barrels in the first half of 2016, or about 2,000 barrels a day, the remaining
364,000 has lost value because the strategy sacrifices protection when prices fall below $40.
Three Parts
The trade has three parts. First, one option capped the best price Callon could get at $65 a barrel.
Selling the right to profit if prices rise offsets the cost of protecting against a decline. The second
piece established a floor price of $55, a guaranteed minimum that Callon would get paid even if oil
fell below that point. By itself, this kind of trade, called a collar, would’ve ensured that Callon
received $25 a barrel protection when oil is trading at $30.
However, Callon added a third element by selling a put option, sometimes called a subfloor, at
$40 a barrel. Below that point, Callon essentially forfeits its protection. Instead of pocketing $55,
the company is only entitled to the difference between the floor and that subfloor, or $15 a barrel
in this case. At $30, Callon will realize $45 a barrel, $10 a barrel less than it would’ve received
with a traditional collar.
If prices rebound above the subfloor, any disadvantage to the three-ways disappears.
‘Risk Management’
"Our hedging program is part of our broader risk management efforts, and is designed to provide
downside protection in a falling commodity price environment," said Eric Williams, a spokesman
for Callon. The price of oil futures through 2016 is at about $35, at which Callon’s three-ways
would yield $50 a barrel, he said.
Representatives for Marathon, Noble and Rex Energy did not return phone calls and e-mails
seeking comment.
Similarly, Pioneer used three-ways to cover 65,000 barrels a day in the first half of 2016, or about
a third of its projected output, company filings show. The strategy capped the upside price at $73
and guaranteed a minimum of $63, which would’ve ensured $33 above a selling price of $30.
However, Pioneer added a subfloor at $43. If oil’s trading at $30 a barrel, Pioneer will get about
$50, or the market price plus the $20 difference between the floor and the subfloor. The difference
adds up. With oil at $40, Pioneer will realize about $845,000 less every day than it would have
using the collar with the $63 floor.
Providing Protection
The protection is still significantly better than nothing. Last year, the company’s hedges brought in
$875 million and they will pay off again in 2016, said Rich Dealy, Pioneer’s chief financial officer.
"Over the past few commodity price cycles, we have learned the importance of using derivatives
to protect margins and cash flow," Dealy said. "We actively manage the types of derivative
instruments we use based on our outlook for prices."
Likewise, Bonanza Creek hedged 5,500 barrels a day for 2016, about 33 percent of its production,
with three-way collars with a ceiling of $96.83 and a floor of $85. At $40, the trade would be worth
about $55 a barrel, or $302,500 a day. However, Bonanza Creek also sold $70 puts, making its
position worth just $15 a barrel, or $82,500 a day.
Ryan Zorn, treasurer and senior vice president of finance for Bonanza Creek, declined to
comment.

"Nobody expected this kind of downward spike," said Haas, the Wunderlich analyst.

NewBase For discussion or further details on the news below you may contact us on +971504822502, Dubai, UAE
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Khaled Malallah Al Awadi,
Energy Consultant
MS & BS Mechanical Engineering (HON), USA
Emarat member since 1990
ASME member since 1995
Hawk Energy member 2010
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 09 February 2016 K. Al Awadi

New base 783 special 09 februaury 2016

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