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September - October 2014
ASIAN OIL & GAS
AOG
Australian
LNG
page 12
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E
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REGIONAL UPDATES
4
Briefs
New discoveries, leases, and development plans.
SHIPYARDS
6
Tiger Drillships Ready for Action
China’s new 170m-long, 32m-wide drillships will be able to
work in water up to 5000ft and drill to 32,900ft. After almost 3
years in development, they are on the verge of delivery.
GEOLOGY & GEOPHYSICS
8
2D Revolution
2
D seismic survey technology and subsurface imaging
techniques are changing the way we search for hydrocarbons.
COVER STORY
10
Australian LNG Fueling Asia
All around the world, countries are investing in LNG
technology. Mary Ching describes the market in Australia.
FEATURES
14
The path is laid for decommissioning in
South East Asia
There are nearly 2000 structures installed offshore in the
Asia Pacific region, all of which will eventually need to be
decommissioned. New ASCOPE guidelines should pave the
way, explains Nina Rach.
16
Myanmar-China Oil and Gas Pipelines:
Rebirth of an Ancient Trade Passage
The Myanmar-China crude oil and natural gas
pipelines are significant in a way that they epitomize a
reincarnation of the ancient southwestern silk trading
route. Mary Ching explains.
COMPANY NEWS
20
Activity
Chinese industrial conglomerate Fosun International Ltd.
will acquire Australia’s Roc Oil Co. Ltd. in an all-cash US$441
million transaction.
CONTRACTS
21
McDermott Wins Indonesion Fab Work
Petronas subsidiary PC Ketapang II Ltd. awarded McDermott
International a fast-track fabrication contract in August.
PRODUCTS & TECHNOLOGY
22
Solutions
AOG staff highlight new tools and techniques designed to
improve operational performance.
PEOPLE
23
Spotlight
US-based project management company Crowley Maritime chose
William Hill as manager for its new Singapore office.
FACTS & FIGURES
24
Numerology
A capsule view of interesting industry statistics.
COVER IMAGE
The loading jetty at the Pluto infrastructure has a single
processing train with production capacity of 4.3 million
tonnes/year. Photo from Woodside Energy Ltd.
Contents
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Regional Briefs
ASIAN OIL & GAS
AOG
September
·
October 2014
Australia
•
ORIGIN ACQUIRES
BROWSE INTEREST
Australia’s Origin Energy acquired
Karoon Gas’ interest in Western
Australia’s Browse basin permits WA-
315-P and WA-398-P for an estimated
US$800 million.
According to Karoon, the Browse
basin gas condensate basin has discov-
ered resource in excess of 30Tcf. It is set
to become a significant source of global
LNG supply with Inpex’s Ichthys project
and Shell’s Prelude projects (currently
under construction) and Woodside’s
Browse LNG project (in FEED).
Origin will be responsible for all costs
associated with the current Pharos-1
exploration well, located in permit WA-
398-P, which encountered hydrocarbon
pay in the Browse basin this July.
China
•
CNOOC DUO BEGINS PRODUCTION
Operator CNOOC Ltd. began production
at its Wenchang 13-6 oilfield and Panyu
10-2/5/8 project, both of which are locat-
ed in the South China Sea. Wenchang’s
main production facilities include one
wellhead platform and 12 producing
wells. There are currently five wells pro-
ducing approximately 1300bbl/d.
The Panyu 10-2/5/8 project is
designed
to share some facilities of Panyu 4-2
oilfield. The new facilities include one
wellhead platform and nine producing
wells. CNOOC says there are four wells
connected, which are producing approxi-
mately 9000b/d. CNOOC expects to reach
peak production of 13,000b/d is expected
by 2015.
Indonesia
•
PGN FSRU
LAMPUNG
BEGINS OPERATIONS
The PGN FSRU
Lampung
project off
Indonesia had its vessel and associ-
ated mooring and pipeline to shore
deemed mechanically complete and
started commercial operation for client
Perusahaan Gas Negara (PGN). The PGN
FSRU
Lampung
received its first cargo
of LNG through a ship-to-ship transfer,
and has now entered its final commis-
sioning phase.
It will be working offshore Labuhan
Maringgai, South Sumatra, Indonesia on
the PGN LNG project. The contract with
PGN is for 20 years.
India
•
GE INVESTS IN WIND PROJECTS
GE Energy Financial Services invested
equity in three Atria Power wind proj-
ects under construction in India.
The wind farms will have a combined
capacity of 126Mw. The first project,
25.6Mw, located in Ananthapur district
of Andhra Pradesh, is expected to reach
commercial operations in September.
Two other projects, each 50Mw, are
located in Betul district of Madhya
Pradesh, and are expected to reach
commercial operations in December and
June 2015 respectively.
The projects will use GE 1.6-87.5
wind turbines, serviced by GE under an
operations and maintenance agreement,
to generate 76Mw of the total capacity.
Additional turbines will be supplied
and serviced by another manufacturer
to generate 50Mw. Atria Power is man-
aging construction and operations.
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Myanmar
•
ENI ENTERS MYANMAR
The Italian major, Eni, signed two
production sharing contracts (PSC) with
Myanmar Production and Exploration
Co. Ltd. (MPRL E&P) for the RSF-5 in the
Salin basin and PSC-K onshore blocks
in the Pegu Yoma-Sittaung basin.
Block RSF-5 covers an area of 1292sq
km in the prolific Salin basin, approxi-
mately 500km north of Yangon. Block
PSC-K covers an area of 6558sq km in
the unexplored Pegu Yoma-Sittaung
basin, in the central part of Myanmar.
This agreement marks Eni’s first entry
into Myanmar. The exploration period
will last six years and subdivided in to
three phases.
Vietnam
•
OFFSHORE VIETNAM DISCOVERY
A consortium of three Japanese ex-
ploration companies, led by operator
Idemitsu Kosan, discovered natural gas
and condensate at the fourth well in
Blocks 05-1b and 05-1c offshore south-
ern Vietnam, about 300km (188mi)
southeast of Ho Chi Minh City.
Spudded in February, natural gas and
condensate were indicated following drill
stem tests carried out in May and August.
Discovery of gas and condensate at
this exploration well follows discovery
of oil and gas accumulations at other
wells drilled in blocks 05-1b and 05-1c.
A detailed reservoir evaluation will be
carried out in conjunction with further
evaluation of other potential prospects
in these blocks.
•
DUA OIL PROJECT
PRODUCTION BEGINS
Oil production has begun at the Dua
oil project, operated by Premier Oil
offshore Vietnam, 40 years after the field
was discovered.
The tie-in from Dua to the Chim Sáo
field in Block 12W was approved by the
government of Vietnam in December
2011 and sanctioned in August 2012.
Subsea installations were completed
in 2013 and tied back to the
Chim Sáo
FPSO via flowlines and umbilicals.
Premier Oil drilled three production
wells at Dua, beginning in February,
using the newbuild West Telesto ILC
jackup, operated by Seadrill.The gross
production rate from the Dua wells
is estimated to average 8000 bo/d for
the first 12 months of production.
Sufficient oil and gas handling capacity
is available on the
Chim Sao
FPSO to
accommodate both
Chim Sao
and
Dua
at
full production.
Thailand
•
SUKSAN SALAMANDER
RECEIVED FIRST OIL
First oil has been received in the
tanks of the newly converted
Suksan
Salamander
floating storage and offload-
ing vessel (FSO) at the Bualuang field
in the Gulf of Thailand, says London-
headquartered Salamander Energy. The
upgrade to the field’s facilities targets
a reduction in operating costs of up to
US$25 million/yr.
The new FSO will operate at half the
day rate of the existing
Rubicon
Vantage
floating production, stor-
age, and offloading (FPSO) ves-
sel. Additionally, the upgrades double
the water-handling capacity, poten-
tially increase production rates, and
extend the productive life of the field.
The
Rubicon Vantage
FPSO will leave
the field in the coming weeks.
•
MANCHAREE-1 DISAPPOINTS
Singapore-based KrisEnergy completed
drilling on the Mancharee-1 well off the
Gulf of Thailand with no significant pay
zones identified.
KrisEnergy says gas shows were
encountered at several levels but no sig-
nificant pay zones were identified.
The West Cressida jackup rig, owned
by Seadrill Far East, drilled to 3720m
total depth in 51.8m of water. The well
is located in license G10/48 in the devel-
oping Wassana oil field, which covers
4696sq km over the southern section of
the Pattani b
asin and is located in up to
60m water depth.
In June, KrisEnergy contracted Shelf
Drilling’s Key Gibraltar jackup for
development, appraisal and exploration
drilling in the G10/48 and G6/48 blocks.
The contract will begin in January 2015
for a firm six-month term with an option
to extend an additional two months.
Philippines
•
CONTRACTING
ROUND LAUNCHED
The Philippines Department of Energy
launched the fifth Philippine Energy
Contracting Round (PECR5) in May,
and scheduled international roadshows
in Texas, Singapore, and Turkey (14-17
September 2014) to encourage oil ex-
ploration players to join the contracting
round. The PECR5 offers 11 areas for
petroleum exploration, most located in
Luzon, and 15 areas for coal exploration,
largely concentrated in Mindanao.
For petroleum, applications will be
accepted until 27 February 2015 (11:00
AM, PST). Applications will be opened
only after the submission period.
For coal, applicants will have until 19
September 2014 (11:00 AM, PST) to file
applications.
Endorsement of winning applicants
for coal and petroleum are planned
for 21 November 2014 and 4 May 2015,
respectively.
Kazakhstan
•
DISCOVERY AT BNG
Oil and gas have been detected at a
depth of 4332m in well A5 of BNG
contract area being drilled onshore
Kazakhstan, Roxi Petroleum an-
nounced. After the completion of clean-
up work to deal with the oil and gas
shows encountered, core samples will
be taken to determine the oil bearing
horizon.
Well A5, the first deep well on the
BNG contract area, with a planned total
depth of 4700m is targeting principally
the middle carboniferous formation at
4390m of the South Emba sub-basin.
The BNG contract area is located in
the west of Kazakhstan 40km southeast
of Tengiz on the edge of the Mangistau
Oblast, covering an area of 1561sq km of
which 1376sq km has 3D seismic cover-
age acquired in 2009 and 2010.
Russia
•
KARA SEA PROSPECT SPUDDED
ExxonMobil began exploratory drill-
ing operations in the Kara Sea’s
Universitetskaya structure in the East
Prinovozemelskiy area in August, defy-
ing Western sanctions against Russian
state-owned Rosneft.
Operations will
last two months. Rosneft said that the
Universitetskaya structure contains
a 55m-high hydrocarbon trap, with
resources of 1.3 billion toe. About 30
structures have been found in three East
Prinovozemelskiy areas of the Kara Sea,
with a resource base totaling 87 billion
boe, Rosneft said. Drilling will take
place at 81m water depth. The Kara Sea
has water depths ranging 40-350m.
While previous sanctions forbid the
US and EU from business transactions
with sanctioned individuals, July’s sanc-
tions specifically intend to deny Rosneft,
and other sectors of the Russian econo-
my, from thriving off Western-based oil
and gas equipment and technology.
AOG
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Shipyards
3Q 2014; [
Tiger II
] will be ready 1Q
2015. The drillships will be cyber-based
and have offline drill pipe and casing
stand building.”
Each ship will have four 7500psi,
2400rpm electric quintaplex mud
pumps, and 15ksi Cameron BOP with
MUX control system.
US-based offshore drilling and pro-
duction equipment provider Drilling
Technological Innovations LLC (DTI)
provided drilling motion compensation
packages for both drillships. The pack-
ages for the Tiger series include DTI’s
slim-design, single-wireline tensioners
with true 200,000-pound capacity at
mid-stroke, advanced riser-recoil sys-
tem, full tensioner system controls and
crown-mounted compensator.
ABB provided the core electrical sys-
tem solutions for the two ships, including
the electric propulsion system, electric
power generation and distribution system,
and drill drives with control systems. The
electric propulsion system is comprised of
drives, transformers, and drive motors.
The new drillships are “ideal for
operations in remote locations where
reduced usage of supply boats make the
Tiger Class a very cost-effective alterna-
tive,” said Burnett.
In April, Opus exercised options to
build two additional CSSC Offshore
Tiger class drillships at the Shanghai
Shipyard.
MAERSK DRILLING
GETS XLE-2 JACKUP
Maersk Drilling took delivery of its
second ultra-harsh environment jack-up,
XLE-2, from the Keppel FELS shipyard
in Singapore in August. It mobilized to
the Norwegian North Sea, where it will
commence a five-year contract with Det
Norske Oljeselskap ASA.
The rig, which will be named at a
ceremony in Norway in October, is the
second in a series of four newbuild ultra
harsh environment jack-up rigs to enter
Maersk Drilling’s rig fleet in 2014-16.
The four jack-up rigs represent a
total investment of US$2.6billion.
The first three jack-up rigs, includ-
ing XLE-2, will be delivered from the
Keppel FELS shipyard in 2014-2015,
and the fourth will be delivered from
the Daewoo Shipbuilding and Marine
Engineering (DSME) shipyard in South
Korea in 2016.
The total estimated contract value is
about US$700 million. Det norske has op-
tions to extend the contract up to a total
of seven years. The rig will be working
on the Ivar Aasen field, which contains
approximately 150 MMboe.
AOG
McDermott will fast-track
BTJT-A jacket in Indonesia
McDermott International, Inc. was awarded a contract by PC Ketapang II Ltd., a subsid-
iary of Petronas, for fast-track fabrication of the BTJT-A jacket for the Bukit Tua develop-
ment project in the Ketapang block, off east Java, Indonesia.
McDermott will fabricate the four-leg, 1100t wellhead jacket from the Batam Island fabri-
cation facility in Indonesia. The project is expected to be complete by mid-November 2014.
“The timing of delivery for this fast-track project is critical,” says Hugh Cuthbertson,
vice president and general manager, Asia Pacific. “We have already commenced fabrica-
tion activities as the jacket must be completed for installation before the start of the
monsoon season.”
Aerial view of
McDermott’s Batam Island yard.
OPUS OFFSHORE READIES TO
RECEIVE TIGER DRILLSHIPS
Tiger I
and
Tiger
II
, the first drill-
ships to be built
in China, for
Opus Offshore
Pte Ltd, are on
the verge of
delivery. The
drillships were
ordered in Sep-
tember 2011, and
construction began on 1 June 2012.
The 170m-long, 32m-wide drillships
are being built under a turnkey con-
tract by
China State Shipbuilding Corp
(CSSC)-affiliated
Shanghai Shipyard
Co. Ltd. The ships will be able to work
in water to 5000ft and drill to 32,900ft
and are classed by ABS. They will be
managed by the Songa-Opus JV, formed
earlier this year.
Peter Burnett, Operations Manager at
Opus Offshore, said:
“
Tiger 1
will be ready for operations
New Opus drillship:
Tiger I
Maersk Drilling’s XLE-2 jack up
drilling rig.
AOG
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September
·
October 2014
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Geology & Geophysics
COSL takes delivery of
12-streamer seismic vessel
China Oilfield Services Ltd. (COSL)
announced on 11 August that its newly
built 12-streamer seismic vessel Hai
Yang Shi You 721 was successfully de-
livered in Shanghai. The vessel will be
put into operation after completing tests
with its geophysical equipment.
Hai Yang Shi You 721, the second major
seismic vessel purchased by COSL, is
capable of towing 12 streamers for seis-
mic data acquisition, each 8000m long.
It can conduct high-density seismic data
collection at a maximum intensity of up
to 3000psi.
Equipped with a new generation
seismic data collection system, an
integrated navigation system, a lateral
streamer control system, a complete
geophysical mechanical remote control
system and an advanced diesel-electric
propulsion system, Hai Yang Shi You
721 is able to deliver high efficiency and
premium seismic data collection quality
at lower fuel consumption, and perform
steadier and quieter operation, accord-
ing to COSL.
COSL’s first seismic acquisition vessel,
Hai Yang Shi You 720, is a sister ship of
the same model and has achieved good
results and hit a number of new records
for COSL’s data collection operations
since its delivery in May 2011 from
Shanghai Shipyard.
COSL is a majority owned subsidiary of
Chinese state-owned company CNOOC
Group.
SeaBird’s
Aquila Explorer
to start 2D surveys
On 31 July 2014, Norway’s
SeaBird Ex-
ploration
Plc reported that the R/V
Aq-
uila Explorer
received a letter of award
for a 2D seismic survey in Australasia.
Under the US$11 million contract, the
2D survey will cover at least 10,000 km
(6213 mi.).
Seabird said the project is expected to
start in 4Q 2014 and will require 90 days
based on the minimum survey size.
Norwegian geophysical contractor
TGS also reported that it would use
the
Aquila Explorer
for a 17,000km, 2D
multi-client survey off northwest New
Zealand.
The
Aquila Explorer
is a 2D long
offset/source survey vessel built in 1981,
and refurbished in Singapore in 2007.
The vessel is 71m long and 17.5m abeam,
with a mean draft of 5.45m.
Earlier this year, the
Aquila Explorer
received a $5.5 million contract for a 2D
seismic survey in the same region.
Searcher begins Pinatubo 2D
broadband seismic survey
Australia’s Searcher Seismic Pty Ltd. has
started shooting the Pinatubo multi-client
2D seismic survey west of Luzon Island,
the largest island of the Philippines.
The 3843km 2D survey is laid out in a
10km x 20km grid over the West Luzon
basin. The survey includes coverage
over the upcoming PECR-5 bid round
blocks 8, 9, 10, and 11.
This area is in the Luzon Sea (Philip-
pine territorial waters), adjacent to the
South China Sea.
Searcher says the Pinatubo 2D survey
is the first modern seismic 2D coverage
over the West Luzon basin. The survey
covers an unexplored area and will
provide data sufficient to define major
structural trends and plan detailed
follow-up surveys.
The Pinatubo multi-client 2D survey
includes long offset, broadband data,
with the following acquisition param-
eters: Sample rate of 2ms; Record length
of 12sec; Streamer length of 10km.
The deliverables will include:
•
Final, full-angle volume (AGC) (in
time and depth)
•
Final, full-angle volume (Raw) (in time
and depth)
•
Filtered and scaled relative amplitude
angle volumes (near, mid, far, ultra far)
(in time and depth)
West Perth-based Searcher says acqui-
sition of the Pinatubo survey will be
completed in late August.
Fast-track data will be available to
ensure ample time for evaluation of the
blocks for PECR5 bidding round.
AOG
Rosneft has reported that on 24 July 2014, the research
vessel
Geolog Dmitry Nalivkin
* sailed from Kirkenes, Norway
to the Kara Sea.
In the next three months, the ship will acquire 2D seismic
data over three Vostochno-Prinovozemelsky license areas.
The field work will be conducted over
almost 7000sq km surface area,
and the results will help identify
and delineate drillable oil and gas
prospects, says Rosneft.
A pre-project meeting was held
aboard the vessel just before it sailed.
Representatives of Karmorneftegaz
(ExxonMobil and Rosneft joint-venture
that organizes the exploration program
in the Rosneft licenses in Kara Sea) met
with specialists from the Marine Arctic
Geological Expedition (MAGE).
The Vostochno-Prinovozemelsky licenses cover
126,000sq km (31million acres), with water depths varying
from 40-50m (120-1000 ft). The ice cover period lasts from
270-300 days/yr.
Rosneft holds 66.7% participating
interest in the joint-venture companies
aiming to develop the Kara Sea and
Black Sea, and ExxonMobil holds
33.3%.
•
*The ship is named for Dimitri
Vasilievich Nalivkin (1889–1982), a
Soviet geologist (stratigrapher) who
mapped much of the geology of the
USSR (The Oxford Companion to The
Earth, 2000).
Rosneft starts Kara Sea seismic acquisition
AOG
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September
·
October 2014
8
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East Prinovozemelsky blocks 1, 2
and 3 in the Kara Sea.
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D
espite aging oil basins, the coun-
try is not keen on taking a back
seat in the oil and gas scene. Natural
gas production and greater LNG capac-
ity are fueling a multi-billion invest-
ments Down Under. Almost $200 billion
worth of LNG projects under construc-
tion, abundance of gas resources, and
strategic location could potentially be
the catalysts for Australia to clinch the
world’s top LNG exporter position by
2020.
Australia is a country with economic
reserves of 1 billion bbl of crude oil, 2.1
billion bbl of condensates, and 1 billion
bbl liquid petroleum gas (LPG) accord-
ing to the Australian government agency,
Geoscience Australia. In 2012, oil produc-
tion summed up to 484,000 b/d, compris-
ing about 50% crude oil, 28% lease con-
densates, 13% LPG, with refining gains
and biofuels making up the remaining
percentage. Statistics have illustrated that
condensates and liquids associated with
natural gas production are progressively
substituting crude oil production.
Oil-producing basins
Australian oil reserves are concentrated mostly off the coasts of Western Australia, Victoria,
and the Northern Territory. Onshore basins are found in Queensland and South Australia,
known as the Cooper basin, though it only accounts for 5% of the country’s oil resources.
Western Australia’s abundant crude oil reserves makes up 64% of the country’s proven
reserves, 75% of its condensate and 58% of its LPG reserves.
The Carnarvon basin in the northwest accounts for 72% of total liquids production. While
the Gippsland basin in southeastern Australia accounts for 24% of total liquids production.
These are the largest oil producing basins in the country. The production from Carnarvon
basin is predominantly exported, while the Gippsland basin oil production is mostly used
in domestic refining. Currently, Australia is not producing oil shale on a commercial basis
due to technical and environmental challenges. However, according to a recent U.S. Energy
Information Administration (EIA) study on world shale oil resources, the country has techni-
cally recoverable reserves of over 17 MMbbl in the state of Queensland.
All around the world,
countries are investing
in LNG technology.
Mary Ching explains the
market in Australia.
Australian LNG
Woodside’s onshore Pluto LNG
terminal located at Burrup
Peninsular.
Photos from Woodside Energy Ltd.
Fueling
Asia
The loading jetty at the Pluto infrastructure which has a single
processing train with production capacity of 4.3 million tonnes a year.
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Oil import surpasses export
In 2012, Australia exported 280,000 b/d of crude oil and con-
densates to Singapore, South Korea, China, Japan, Thailand,
and Malaysia. Countries such as Japan utilize these imports
for direct crude burning in electric power plants. Australian
crude oil is light, and is low in sulfur and wax, with higher
value than heavier crudes.
However, oil production in Australia has been decreasing
since 2000 because of maturing basins. Productions from new
fields will not been able to offset declines from aging basins
unless more fields are discovered.
To meet rising domestic oil consumption, the country has
to increasingly import oil. Australia imported 234,000 b/d net
crude oil, and 294,000 b/d net oil products in 2012. Singapore
provides about 60% of the overall oil products imported
into North Australia and Northwest Australia. This is due to
the lack of adequate regional refining capacity in North and
Northwestern Australia, whereas eastern Australia imports
crude oil for its refineries and domestic markets. Although
much of Australia’s oil production is located off its northwest
coast, the crude oil and condensates produced there are ex-
ported to Asian refineries.
For instance, in 2012, countries like Malaysia, Nigeria,
United Arab Emirates, and Indonesia supplied more than half
of the total crude oil imports (55%) into Australia. The second
tier of crude oil supplies (about 22%) is contributed by African
countries such as West Africa, Nigeria, Congo, and Gabon.
Gas resources
Australia is endowed with an abundance of natural gas
for its domestic consumption as well as for export pur-
pose. The country has more than 800 trillion cubic feet
(tcf) of gas resources and this number is growing with new
explorations unlocking more gas. New gas discoveries in
Australia have caused a recent influx of investments into
the country. Increased demand for gas in the Asia
Pacific region has also boosted investors’ confidence in
Australian gas.
Approximately 92% of traditional gas resources are located
in the North West Shelf (NWS) offshore. The majority of
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traditional gas resources are supplied by 10 massive fields in
the Carnarvon, Browse, and Bonaparte basins. The production
from these giant fields surpass the production from almost
500 other gas fields in Australia.
In terms of technically recoverable shale gas reserves, ac-
cording to the U.S. EIA study Technically Recoverable Shale
Oil and Shale Gas Resources, Australia had an estimated
437tcf in 2012. From the inland Cooper basin and the eastern
Maryborough basin to the offshore southwestern Perth basin
and the northwestern Canning basin, these recoverable shale
gas reserves are scattered throughout Australia.
LNG export
Accompanying Australia’s oil production decline, natural
gas production has increased in the past decade. Buoyed by
new developments, Australia has become the third-largest
liquefied natural gas (LNG) exporter in the world, after Qatar
and Malaysia. Australia is delivering reliable and cleaner
energy to Asia Pacific. From 2012 to 2013, Australia ranked
in $13.7 billion in LNG export revenue. Experts calculated
that Australian LNG exports will quadruple over the next five
years.
With LNG export of about 990 billion cubic feet (bcf) in 2012,
Australia’s vast gas resources and strategic location in close
proximity to Asian markets provided the platform for the up-
surge in LNG export. New exploration activities and liquefac-
tion capacity also substantiated the steady growth in export.
The main market for Australia’s LNG export is Japan, fol-
lowed by other Asian consumers namely China, South Korea,
and Taiwan. Exports to Japan started to intensify in 2011
with the dawn of Japan’s natural gas-fired generation, which
replaced the nuclear power plant as a result of the Fukushima
Daiichi nuclear disaster.
Another significant market is China with whom a number of
Australian liquefaction projects and gas purchase contracts have
been inked to provide supply for the escalating Chinese demand.
LNG terminals, increased capacity
Buttressed by three LNG export facilities, Australia has a
total export capacity of about 1.2 billion cubic feet per year.
Featuring five offshore LNG trains with a total capacity of
780 billion cubic feet per year, the North
West Shelf is the largest LNG facility in
Australia. It exports most of its produc-
tion to Japan in order to fulfil long-term
supply agreements. Whereas Darwin LNG
is Australia’s second LNG facility consist-
ing a production train with the capacity
of 170 billion cubic feet per year. Situated
at Australia’s northern coast, it also serves
export contracts to Japan, utilizing natu-
ral gas from the Bayu-Undan field in the
Timor Sea. Trade with the Japanese is
evidently paramount to Australia’s success
in securing its position as one of the global
leaders in LNG exporter. The latest addi-
tion to Australia’s LNG facility is the Pluto
terminal at the Northwest region. Since its
inception in 2012, the Pluto facility has one
train with a capacity of over 200 billion
cubic feet per year which supplies to Japan
and Malaysia markets. Expansion plans are
in progress from Woodside, which holds a 90 percent equity
share in Pluto. However, challenges are present in obtaining
more gas reserves from fields in the vicinity as well as high
project costs.
To maintain its position in LNG export and to ensure expo-
nential growth in the future, new liquefaction facilities are
currently under construction as well as expansion of current
terminals. A total of seven projects in Queensland, coastal
and offshore Northwest Australia are under construction
and are expected to provide an estimated operation of 3 tcf/
year by 2017. This additional supply of LNG will be exported
to meet growing demand in Japan, Korea, China, Taiwan,
and Malaysia as well as tackling potential markets such as
India, Singapore, Mexico and Chile. A considerable number of
projects are also in the planning stages, some are pending on
legal issues and final investment decisions. With almost $200
billion worth of LNG projects under construction, this could
potentially propel Australia to overtake Qatar at the forefront
of LNG trade by the turn of the decade.
Opportunities for development are also paired with con-
straints. Current projects under construction such as Ichthys,
Gorgon, Wheatstone, Gladstone, and Queensland Curtis
are burdened by high costs. For instance, Gorgon LNG proj-
ect reported that such costs had amplified by more than 40
percent from US$37 billion to US$52 billion. Cost challenges
were manifested by issues such as the lack of workers which
subsequently affected the high cost of wages. Access to certain
remote areas and environmental issues can incur very high
project costs too. The appreciation of the Australian dollar to
the U.S. dollar since 2009 also contributed to cost challenges.
Overall capital expenses for newer projects have also sky rock-
eted and posed potential threats for new projects to be post-
poned or abandoned.
With rising project costs, businesses could see changing
trends. Perhaps some will emphasize on expanding existing fa-
cilities to increase production instead of developing new fields
and new projects. Nevertheless, even in a flourishing industry,
competition cannot be excluded in the future as Australia may
have to compete with exporting countries such as Russia and
the United States.
AOG
- Source: U.S. Energy Information Administration.
Woodside, one of the world’s leading LNG producers, holds a majority share in the
Pluto project.
Photo: Woodside Energy Ltd.
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Petroleum Exhibition & Conference of Mexico
For 21 years, PECOM has been helping
companies connect and succeed in
Mexico’s oil and gas industry. Now,
with Mexico’s recently signed energy
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April
14-16
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AOG
|
September
·
October 2014
14
aogdigital.com
T
here are more than 600 offshore installations over 25
years old in Asia Pacific, company portfolios of older
structures are growing, and decommissioning in the region is
only just beginning.
Options for retiring structures include complete removal,
removal to the seabed, removal to the footings, leave in place,
topple to the seabed in situ, as an artificial reef, remove to sea-
bed and transport to a different artificial reef site, or remove to
elevation, which means to remove all steel to a depth of 55m
below the lowest astronomical tide.
Decommissioning offshore structures presents numerous
challenges, and many projects require bespoke plans. In ad-
dition to ubiquitous health and safety concerns in managing
heavy lifts of objects of unknown integrity, subsea activities,
and hazardous materials, the potential environmental impacts
must be well thought out and mitigation procedures estab-
lished. Lifting capacity is a limiting factor. Subsea cutting
equipment is available for steel members up to 3m in diam-
eter, assuming there is physical access. A majority of the dis-
mantling, cutting, and sectioning must take place offshore, as
few docks can support the offloading of large pieces of steel.
Decommissioning was actually mentioned in the Geneva
Convention of 1958, at a time when offshore structures were
much smaller and simpler, and expectations were that they
would be totally removed when they were retired.
The agreement was superseded in 1982 by the United Nations
Convention on the Law of the Sea (UNCLOS) which referred to
permitting requirements for leaving man-made structures in
the marine environment. In 1989, the International Maritime
Organization (IMO) published guidelines and standards for the
removal of offshore installations and structures.
North Sea
Now, the OSPAR Convention governs the decommissioning of
offshore structures in the North Sea area. As of February 1999,
it requires all redundant man-made structures to be removed
for disposal on land, except for concrete, gravity-based struc-
tures and the footings of steel-piled jackets (SPJ) installed
before 1999, where the installed jacket exceeds 10,000 tonnes.
Self-floating steel piled jackets weigh more than 12000
tonnes and were only installed in the 1970s and 1980s; none
have been decommissioned yet. Barge-launched jackets gener-
ally weigh between 5000 and 25000 tonnes. Lift installed
structures weigh less than 10,000 tonnes. Shallow-water
jackets usually weigh less than 2000 tonnes and are installed
in water less than 55m deep.
The OSPAR Commission reviews requirements every five
years and considers amendments based on proposals by
OSPAR contracting parties and the availability of new tech-
nology. Following amendments in 2008, it was noted that no
technology yet exists to safely cut large sections of SPJ foot-
ings and grout-filled pile clusters.
It’s unclear whether the recent completion of Allseas’ new,
gigantic, twin-hull
Pieter Schelte
heavy-lift vessel will change
OSPAR regulations.
ASCOPE guideline development
The ASEAN Council on Petroleum (ASCOPE) is the associa-
tion of national oil companies in the Association of South
East Asian Nations (ASEAN) region. It was established on
15 October 1975 in Jakarta, Indonesia as an “instrument for
regional cooperation among member countries.
ASCOPE coordinates with the Coordinating Committee for
Geoscience Programs in East and Southeast Asia (CCOP), an
intergovernmental organization whose mission is to facilitate
and coordinate the implementation of applied geoscience
programs, with 12 regional members.
At the 15
th
ASCOPE Exploration and Production Business
Development Committee (E&P BDC) meeting in September
2006, it was noted that 54% of the installed platforms/offshore
There are nearly 2000 structures installed offshore
in the Asia Pacific region, all of which will eventually
need to be decommissioned. New ASCOPE
guidelines should pave the way, explains Nina Rach.
The path is laid
for decommissioning
in South East Asia
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structures in the area are more than 20 years old, and ASCOPE
members could benefit from a collaborative approach toward
developing “unconventional” decommissioning solutions.
During the 16th E&P BDC meeting in May 2007, it was decid-
ed that ASCOPE Member Countries would cooperate to come
up with a regional convention decommissioning reference
document, with technical assistance from Petrad. Also, each
ASCOPE member country would formulate its own decommis-
sioning guidelines.
At the 17th E&P BDC meeting in September 2007, Malaysia
proposed a regional effort to share resources and Thailand
proposed to have common decommissioning guidelines.
At the 18th E&P BDC meeting, Norway’s Petrad conducted a
one-day workshop prior to establishing a regional decommis-
sioning guideline.
At the 19th E&P BDC meeting in August 2008, ASCOPE
formed the Decommissioning Guidelines (ADG) Task Force, set
up terms of reference, and put together a two-year roadmap.
The road map was revised in 2009, with the decision to
share historical data and leverage with Petrad and CCOP as
consulting bodies to benchmark with other regions. It was also
decided that the ADG task force would meet quarterly to draft
the Guideline, and that country chapters of ASCOPE should
attend decommissioning conferences in key decommissioning
areas, such as the North Sea and the Gulf of Mexico. The task
force would also investigate technologies for heavy lifting, un-
derwater cutting, environmental monitoring and remediation,
and look into salvage, reuse, and refurbish options.
Over the next two years, the ADG task force issued a draft
version of the Decommissioning Guideline for comment,
and selected a technical editor. In December 2011, ASCOPE
engaged Reverse Engineering Services Ltd. (RESL), based in
Manchester, England, to edit the ADG Guidelines, with input
from member countries.
Brian Twomey, RESL Managing Director, said the company
reviewed the onshore and offshore decommissioning guide-
lines of other countries such as the United Kingdom (UK),
Norway, United States (US Idle Iron), and Australia, among
others.
ADG
The guidelines were completed in 2013 and launched at the 38th
ASCOPE Council Meeting (ACM), held in Yangon, Myanmar.
ASCOPE Decommissioning Guidelines (ADG) provide a
common technical reference for ASEAN countries for decom-
missioning. The guideline aims to establish a balance between
environmental protection, cost, safety and technical consid-
erations in accordance with applicable global and regional
conventions and guidelines.
The Guidelines include: Introduction; International Decom-
missioning Law and Regulations; Technical Decommissioning
& Disposal Options; Impact Assessment; Residual Liability in
Decommissioning; and References.
In 2013, Twomey said the new ASCOPE Decommissioning
Gu
idelines will hopefully lay the foundation for a regulatory
regime in Asia that is more flexible than those found in Europe
and the United States, as operators need “clarity, simplicity and
flexibility” to manage their growing decommissioning burden.
Costs
In March 2010, Twomey published a review of decommission-
ing costs in the Asia-Pacific region. At that time, the region
had more than 1700 offshore installations, and companies
have installed an average of 86/year, during the preceding
decade. About 95% of the structures are fixed jackets, 3%
FPSOs, and 2% TLPs, with a smattering of other types.
Twomey’s data showed that about 48% of the offshore
installations were more than 20 years old in 2010, and nearly
12% were more than 30 years old. A few (16) were even greater
than 40 years old.
In 2010, Indonesia had about 500 offshore structures, with
more than 300 of them characterized as small platforms,
tripods, or single wellhead platforms in the Java Sea north of
Jakarta. Others are in East Kalimantan, in Java off Surabaya,
Gresi, and Pasurian, and off Sumatra in the Straits of Malacca.
More than 50% of Indonesia’s offshore facilities are greater
than 20 years old.
At the same time, Malaysia had about 250 offshore struc-
tures off Peninsular Malaysia, Sarawak, Sabah, and the
Malaysia-Thailand Joint Authority. (The MJTA was formed to
manage exploration in disputed and territorial waters in the
Gulf of Thailand.) Nearly 50% of Malaysia’s offshore installa-
tions had exceeded their 25-yr design life, including 28% off
Sarawak, 12% off Sabah, and 8% of Peninsular Malaysia.
Most (85%) of Asia-Pacific’s offshore installations are in
shallow water, less than 75m, but more than 200 are in water
deeper than 75m. There are only a handful of gravity-based
structures, led by the mammoth, 102,500-tonne Malampaya
platform off the Philippines. About 54% of structures actually
weigh less than 2000 tonnes and are in shallow water.
To determine the future cost burden of the existing offshore
installations, Twomey considered available cost data, and the
average cost to remove per tonne and per facility. He excluded
well P&A and subsea installation costs, assumed pipelines
would be left in place, and assumed that the offshore struc-
tures would be totally removed.
Costs could only be estimated for 819 offshore facilities
(roughly half of the 1732 facilities then counted), and at the
time, would cost US$15.2 billion to remove. Twomely consid-
ered that the total cost for all “could be as high as $32 billion.”
Four years later, with new ASCOPE guidelines, we may yet
see a push to safely retire some of the older iron.
AOG
The Iwaki platform, partially dismantled.
Photo by Nathan Paculba.
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M
ore than two thousand years ago, the southwestern
Silk Road was the great link between China and other
South Asian regions including India, depicting a flourishing
route for trade and cultural exchanges from one civilization
to another. Likened to a modern day adaptation of the ancient
south western Silk Road, the Myanmar-China crude oil and
natural gas pipelines are not just modes of transporting re-
sources for export and import, they are the catalysts that bring
waves of political, economic and social transformations in
the newly emerging Myanmar and rising capitalist China. The
pipelines stretch from the Kyaukphyu port in the Bay of Ben-
gal, Myanmar to Kunming in the Yunnan Province of China.
According to China National Petroleum Corp. (CNPC) and
Xinhua News Agency, the Myanmar-China Pipelines proj-
ect has contributed many positive elements to the lives of
Myanmar population. They have provided employment for
more than a thousand Myanmar employees, which accounts
for more than half of their project staff. The project companies
have also donated millions of dollars to Myanmar communi-
ties to develop educational programs and medical treatment
facilities. CNPC has also agreed to reimburse the Myanmar
government US$13.6 million/yr in the form of rent for the
crude oil pipeline, along with US$1 for every ton that flows
through it, assuming the oil pipeline operates at full capacity.
In the beginning
Early discussions on the pipelines started between the two
nations in 2004. Subsequently, China’s interest in purchas-
ing natural gas was cemented in long-term contracts span-
ning three decades, which PetroChina and the government of
Myanmar signed in 2005. This was the basis for the agree-
ment signed by CNPC (the parent company of PetroChina) and
the Daewoo International consortium in 2008, to purchase the
natural gas produced from the offshore Shwe gas field in the
Andaman Sea.
The Daewoo International consortium is comprised Myan-
ma Oil and Gas Enterprise, India’s Oil and Natural Gas Corp.
(ONGC), GAIL, and Korea Gas Corp., with Daewoo leading the
gas field operation.
The Shwe natural gas field has a total proven reserve of ap-
proximately 9.1 trillion cubic feet (tcf). It was discovered in
The Myanmar-China crude oil and
natural gas pipelines are significant
in a way that they epitomize
a reincarnation of the ancient
southwestern silk trading route.
Mary Ching explains.
Myanmar-China Oil and Gas Pipelines:
Rebirth of an Ancient
2004 by Daewoo and has an estimated production rate of 700
million cubic feet/day (mcf/d).
Dual construction
In 2009, Myanmar and China brought their plans further by
signing an agreement to construct a crude oil pipeline and a gas
pipeline that run parallel, starting at Kyaukphyu and passing
through Mandalay, Lashio and Muse in Myanmar, and con-
tinues through the Chinese border city of Ruili the in Yunnan
Province. The pipelines then continue to Kunming, in south-
western Yunnan, where the oil pipeline then terminates.
The gas pipeline extends further—an additional 2035km—
reaching Guizhou Province and the Guangxi region of China.
Overall, the oil pipeline measures 771km in length, while the
gas pipeline is 2806km long. Construction costs for the oil
pipeline and the gas pipeline were reported to be US$1.5 bil-
lion and US$1.04 billion, respectively.
In 2013, construction of the gas pipeline concluded and the
line became fully operational.
However, construction of the oil pipeline has evidently due
to various obstacles and challenges. Although the oil pipeline
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17
aogdigital.com
was scheduled to commence operations early this year, inter-
nal conflicts, protests from both Chinese and Myanmar locals,
China’s overcapacity and economic slow-down have caused
the oil pipeline project to be postponed.
Oil pipeline as a channel to avoid sea traffic
The onshore crude oil pipeline was primarily designed as
a plan for alternative trading route for oil imports from the
Middle East and Africa, which transits through the Strait of
Malacca. This 800km waterway stretches between Indone-
sia, Malaysia and Singapore. It connects the Andaman Sea
(Indian Ocean) with the South China Sea (Pacific Ocean).
This important shipping lane offers the shortest distance by
sea for Persian Gulf exporters to reach China, Japan, South
Korea and the Pacific countries. Almost 80% of China’s crude
oil imports navigate through the Strait of Malacca, which
is teeming with more than 60,000 vessels every year. The
Strait of Malacca had about 15.2 million b/d of crude oil flow
in 2011.These factors indicate the bustling waterway is a
potential choke point with possibilities of collisions, ground-
ing/stranding and oil spills. Apart from that, ships traversing
through the Strait of Malacca are at risk of attempted theft and
hijackings from pirates.
China solidifies its goal as gas pipeline operates
The Myanmar-China gas pipeline has a capacity of 424 bcf/
yr. Since 4Q 2013, Myanmar has been exporting gas to China
through the pipeline. It began to export its first production at
182 bcf/yr, which exceeded China’s expectation of receiving
146 bcf/yr. Now, Myanmar has secured a new business portfo-
lio in exporting gas to the world’s greatest trading nation.
As for China, the gas pipeline is an additional avenue for
the country to source for more gas and diversify its gas supply
to ensure sustainability in the future. It is also anticipated
Trade Passage
Large image: China eyes to revive the ‘Southwestern Silk Route’ for its economic and trade sustainability.
Photo by Rob Parciasepe.
Left: One of the construction sites of the Myanmar-China oil and gas pipelines. According to the Shwe Gas Movement, local work-
ers were treated unfairly with low wages and poor working conditions.
Above: Local students traverse to and from school along
trails which have been destroyed during the pipelines construction.
Photos from Shwe Gas Movement.
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that the pipeline will deliver up to its maximum capacity
when more gas fields in Myanmar are developed. Hence, Chi-
na’s gas imports through pipelines are soaring as Myanmar
and other countries including Central Asia increase produc-
tion to appease the growing demand for gas in China.
Controversy-laden projects
Despite rendering economic benefits to both China and
Myanmar while forging political ties, the reputation of the
Myanmar-China oil and gas pipelines project has often been
slated as a controversial operation. Charges of exploitation,
unfair treatment, environmental hazards, politics, and safety
issues have caused numerous protests and resistance amongst
these two nations.
Resistance from the Chinese public regarding the construc-
tion of the Anning refinery in Kunming is one of the hurdles
faced by the the oil pipeline planners. With a maximum
capacity of 440,000 b/d, the crude oil pipeline is designed to
supply oil to the proposed Anning refinery which requires
200,000 b/d to produce gasoline and diesel efficiently while
feeding a nearby petrochemicals plant. Thousands of Kun-
ming residents protested CNPC’s construction of the refinery
on the grounds of environmental pollution with emission of
carcinogenic chemicals.
Moreover, the Chinese economy is experiencing decline
and overcapacity resulting in a hold back in energy develop-
ment. The construction delay at the Anning refinery follows a
number of other massive refineries and petrochemical projects
being postponed.
Equally controversial is the resistance from the Myanmar
public on the oil pipeline construction which also has been
delaying the project completion. The people of Myanmar and
human rights activists have staged protests against the oil
and gas pipelines by voicing complaints over unfair compen-
sations for land confiscation. The local Myanmar residents
complained that they had to abandon their homes and lands
without proper compensations in order to give way to the
project. Complaints on environmental and safety issues were
also aggressively raised. Some protestors have stated that it is
not justifiable for Myanmar to export gas while a majority of
its population is stranded in poor living conditions without
electricity.
Furthermore, there is a growing resentment against China
amongst the Myanmar nationalities, many who believe that the
Chinese are exploiting their land and natural resources while
infringing upon their local interests. It is a common percep-
tion among Myanmar locals and critics that profits reaped by
t
he Chinese from oil and gas projects outweigh the benefits
obtained by the people of Myanmar. These sentiments, stemmed
from past political, economic and social issues with China, con-
tinue to permeate through Myanmar communities. Under all
these circumstances, it has been reported that the oil pipeline is
presently being scheduled for completion in 2016.
Repeating history
In light of the southwestern Silk Road, China has been foster-
ing ties with Myanmar to access the ports at the Bay of Bengal,
a strategic trade starting point for immeasurable amount of Chi-
nese goods to be shipped to Europe and a gateway for oil import
from the Middle East to reach China.
China will achieve a milestone in resurrecting a south-
western ancient passage that once prospered with trade and
cultural diffusions. Once again, China is attempting to conduct
more trading activities with India, the Middle East and Europe
across this history-filled route. The Myanmar-China oil and
gas pipelines project is an illustration of these visions. So, will
history repeat itself? Many are of the opinion that China always
seems to have the prerogative in trading business.
AOG
Above: The loading jetty at the Pluto infrastructure which has a single processing
train with production capacity of 4.3 million tonne/yr.
Photo from Woodside Energy Ltd.
Left: Women from the Arakan State, where the gas that
supplies the pipeline originates, still need to collect firewood as a source of cooking fuel.
Photo from Shwe Gas Movement.
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Activity
KrisEnergy adds Chevron’s
Cambodian assets
Singapore-based
KrisEnergy
will
acquire
Chevron Overseas Petroleum
(Cambodia) Ltd. for US$65 million.
Chevron’s Cambodia unit holds a 30%
participating interest in and operator-
ship of offshore asset, Cambodia block
A. Chevron Cambodia’s 30% participat-
ing interest in Cambodia Block A will
reduce to 28.5% once the Cambodian
National Petroleum Authority (CNPA)
completes its acquisition of a 5% par-
ticipating interest in the block. Pre-
transaction, KrisEnergy held an indirect
25% participating interest in Cambodia
Block A, which will reduce to 23.75%
post transfer to CNPA.
Once the acquisition is final,
KrisEnergy will indirectly hold 52.25%
participating interest in the devel-
opment block. Its partners include:
MOECO Cambodia Co. Ltd. (28.5% WI),
GS Energy (14.25%) and CNPA (5%) once
formal transfer is approved.
Block A is approximately 6278sq km
over the Khmer Trough, offshore
Cambodia. The contract area covers
4709sq km over the Khmer basin in the
Gulf of Thailand where water depths
range from 50- 80m.
The agreement includes renam-
ing Chevron Cambodia to KrisEnergy
(Apsara).
Vung Tau Rig Services
established
Semco Maritime and
PetroVietnam Marine Shipyard (PVMS)
establish Vung Tau Rig Services in
Vietnam to repair, refurbish and up-
grade rigs.
The prospects for upgrades in the
Southeast Asian offshore rig market are
positive. Some 25 rigs are currently op-
erating in Vietnamese waters and the ac-
cess to upgrades in Vietnam will appeal
to rig owners now having an alternative
to moving their rigs to Singapore to have
them upgraded, says Semco Maritime.
Vung Tau Rig Services is looking for
facilities to allow for upgrades of even
larger rigs.
Exova Group expands into India
Exova Group
will expand its reach into
India with the recent acquisition of
Mumbai-based Metallurgical Services
Private Ltd. Exova says
the move will support the expansion of
its offerings to customers in emerging
Asian markets.
“Demand for specialist testing in the
Indian subcontinent is expected to grow
as a result of significant industrial and
infrastructure investment, expansion
of global manufacturing operations and
increased regulatory requirements,” the
company says.This is Exova’s sixth ac-
quisition within the past year, CEO Ian
El-Mokadem said, extending the com-
pany’s reach to 23 countries worldwide.
Sumatec Resources Bhd to buy
Borneo Energy Oil and Gas Ltd.
Malaysia’s
Sumatec Resources
Bhd
plans to buy Kazakhstan’s
Borneo Energy Oil and Gas Ltd.
for
US$250million (RM800million) in cash
and shares.
Sumatec announced on 11 July 2014
that it had signed a framework agree-
ment with Abu Talib Abdul Rahman
and Dr. Murat Safin to buy Borneo
Energy, which owns 100% of Buzachi
Neft LLP.
Buzachi is an independent upstream
oil and gas player incorporated in
Kazakhstan and its activities include
exploration, production, and trading of
oil and natural gas.
Buzachi has two, 25-year subsoil
use contracts, running until November
2026, to explore and produce oil and gas
in Karaturun Vostochnyi and Karaturun
Morskoi fields, which are also known
as the Buzachi fields, in northern
Kazakhstan.
The fields started production in 2007
are producing between 400 and 600
bo/d.
Sumatec CEO Chris Dalton said
Sumatec could easily ramp up produc-
tion as soon as it completes the pro-
posed acquisition.
AOG
Fosun Chairman Guo Guangchang
speaks at the China Europe International
Business School.
Photo from CEIBS.
AOG
|
September
·
October 2014
20
aogdigital.com
Fosun to buy Roc Oil
Chinese industrial conglomerate
Fosun International Ltd.
will acquire
Australia’s Roc Oil Co. Ltd. in an all-
cash US$441 million transaction.
Sydney-based Roc Oil maintains as-
sets from Australia to Malaysia, China,
and the UK North Sea, which produced
2.7MMboe in 2013, and earned a net
profit of US$45.2 million.
“The reason for the company enter-
ing into the Bid Implementation Agree-
ment, and the Proposed Transaction,
is to enable the group to enter the up-
stream oil & gas industry and acquire
oil & gas assets,” Fosun said in a statement
to the Hong Kong stock exchange.
Roc Oil had been in previous merger
discussions with Horizon Oil, but ac-
cepted Fosun’s all-cash buyout offer of
A$0.69/share on 4 August 2014. Roc Oil
has stakes in projects backed by Petro-
China and CNOOC. Fosun will get assets in
China’s Bohai Bay and Beibu Gulf, “provid-
ing stable upstream income and a learning
ground for further exploration in the region
as China moves more into offshore pro-
duction,” said Wu Fei, a Hong Kong-based
energy analyst at Bocom International
Securities.
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Contracts
•
MACGREGOR WINS
SUBSEA CRANE SUPPLY
Chinese shipbuilder Fujian
Mawei Shipbuilding Ltd.
awarded MacGregor a contract
for two 100-tonne active
heave-compensated subsea
cranes. The cranes will be
fitted to two 86m multipur-
pose platform supply vessels
under construction in Fuzhou,
China. Delivery is scheduled
for the end of September and
October 2015. This order
builds on a 2013 contract for
eight cranes for installation on
a new series of four compact
semisubmersible offshore
accommodation vessels for
Marine Assets Corp.
•
PETRONAS, QINTERRA
SIGN SERVICE PACT
Petronas Carigali Snd Bhd and
Qinterra Technologies signed a
contract worth approximately
US$20miliion to support
Petronas’ Malaysia operations.
Under the three-year agree-
ment, Qinterra Technologies
will provide tractor services
for all of Petronas offshore as-
sets. The scope for work covers
more than 50 wells, which will
see the introduction of next
generation tractor applications,
including debris collector
and rotational equipment.
Qinterra has had a presence in
Malaysia since 2008 and is one
of the brands formed from the
restructure of Aker Solutions
and EQT VI in January 2014.
•
PERTAMINA IN
MATINDOK
DEVELOPMENT DEAL
Indonesia’s PT Pertamina
EP awarded a lump sum
contract for the Matindok
Gas Development project to
a consortium composed of
Technip and PT Wijaya Karya
(Persero) Tbk (WIKA).
The contract covers the
engineering, procurement,
construction and instal-
lation of gas well pads, as
well as flowlines, pipelines;
a central processing plant
(672 million cu m/yr of gas)
with gas treatment facilities
such as acid gas removal and
sulphur removal, and related
infrastructure.
Sweet gas from Matindok
central processing plant will
be sent to the Donggi Senoro
liquefied natural gas (LNG)
plant.
Technip’s operating center
in Jakarta will carry out the
detailed engineering, pro-
curement of critical process
equipment, while WIKA
will carry out the construc-
tion activities along with the
procurement of major items.
The project is scheduled for
completion by 1H 2016.
The Matindok develop-
ment is an onshore project in
Central Sulawesi, compris-
ing the Donggi, Matindok,
Maleoraja and Minahaki
fields. It produces about
1Bcm/y of natural gas and is
solely owned by Pertamina.
•
BUMI TO SUPPLY
FPSO OFF INDONESIA
Husky-CNOOC Madura Ltd.
granted Malaysia-based Bumi
Armada Offshore Holdings
Ltd. and its joint venture
company PT Armada Gema
Nusantara a contract to pro-
vide the floating production,
storage and offloading (FPSO)
vessel for the Madura BD
Field, located approximately
65km east of Surabaya and
about 16km south of Madura
Island, offshore Indonesia.
The contract is worth an es-
timated US$1.18 billion for a
fixed period of 10 years with
options of five extensions
worth an aggregate value of
$147 million.
The contract will be finalized
by late September 2014.
•
HONGHUA OFFSHORE
WINS SEMISUB ORDER
Orion Engineering and
Management Ltd. signed a
letter of agreement with Hong
Kong’s Honghua Offshore Oil
& Gas Equipment to build a
semisubmersible drilling rig
for about US$320 million.
According to the LOA, the
agreement is expected to be
executed within 60 days. At
the same time, Orion has the
option to purchase three addi-
tional rig units with the same
specification from Honghua
Offshore under the same
conditions, at intervals of six
months. The rig and option
units under the LOA will be
equipped with the company’s
in-house designed and manu-
factured drilling package.
Meanwhile, Orion will
contract a subsidiary of Opus
Offshore Ltd. to supervise the
construction of the rig.
•
INDONESIA ORDERS
FIRST CNG CARRIER
Pelayaran Bahtera Adhiguna,
a subsidiary of Indonesia’s
state-owned power company
Perusahaan Listrik Negara (PT
PLN) chose Qingdao Wuchuan
Heavy Industry’s shipyard in
northern China to build the
world’s first compressed natu-
ral gas (CNG) carrier.
The carrier will transport
natural gas from Indonesian
fields in East Java to the
island of Lombok.
The CNG carrier has been
designed by China’s CIMC
Ocean Engineering Design &
Research Institute, and will
be classed by ABS and by the
Indonesian class society Biro
Klasifikasi Indonesia.
AOG
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·
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|
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21
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Solutions
displayed on the bridge of the vessel.
www.amarcon.com
Mitsubishi launches
wind Lidar system
Tokyo-
headquar-
tered
Mitsubishi
Electric
launched
its compact
wind lidar
technology. Lidar, combining light and
radar, is a remote sensing apparatus that
projects a laser beam and then evaluates
the reflected light to measure wind
speed.
Mitsubishi’s compact wind lidar can
measure wind remotely at multiple alti-
tudes for accurate assessment and predic-
tion of wind-turbine power generation,
and features improved environmental
tolerance for diverse operation.
It has an increased tolerance to extreme
environmental conditions, including
water resistance to IP67 and temperatures
down to -20°C, has a reduced power
consumption and a small profile for easy
operation, and has motion compensation
for offshore use supports floating wind
turbines.
The Energy Research Centre of the
Netherlands conducted tests to validate
and subsequently approved Mitsubishi
Electric’s compact wind lidar as comply-
ing with European wind measurement
standards.
www.mitsubishielectric.com
GE introduces iQ VideoProbe
The GE Mentor Visual iQ
Video Probe.
Photo from GE.
GE’s Measure-
ment and
Control
business
introduced a
new video
borescope
– the GE
Mentor Visual
iQ VideoProbe. With the devic
e, techni-
cians employ non-destructive testing
(NDT) techniques, such as visual
inspections, to alert technicians to any
material or component indications that
can adversely affect the integrity or
safety of the equipment. Designed for use
across several industries, GE Mentor
Visual iQ VideoProbe is equipped with
an touchscreen interface, on-screen
keyboard and ergonomic buttons. Menu
directed inspection (MDI) guides users
through the inspection process and
organizes results for simplified reporting.
Equipped with Bluetooth and Wi-Fi
connectivity, and similar to GE’s newly
launched Mentor EM, the GE Mentor
Visual iQ VideoProbe is built for
real-time collaboration. Harnessing the
power of the Industrial Internet, inspec-
tion technicians will be able to connect
directly with experts from the field to get
advice, share screens and images of the
inspection site, make notes, and more
accurately assess the area, helping to
expedite the inspection process.
The quick change probes with multiple
lengths and diameters and tip optics
speed the inspection process by allow-
ing technicians to identify more indica-
tions and collect more data with a single
system. The 3D Phase Measurement
capabilities help determine accurate indi-
cation depth and size for pitting, cracking
and corrosion.
www.ge.com
AOG
Pan Ocean orders
Octopus-Onboard
Korean-based global shipping company
Pan Ocean ordered OCTOPUS-Onboard
system from ABB subsidiary Amarcon
for two semisubmersible heavy lift ves-
sels, the
Sun Rise
and the
Sun Shine
.
The state-of-the-art ship monitoring
and advisory system will support the
vessels’ route planning, optimization of
speed, heading, and fuel consumption.
Amarcon will deliver an OCTOPUS-
Onboard installation including motion
monitoring and forecasting. The system
will increase workability and safety dur-
ing heavy lift transportation projects. A
motion monitor system (TMS-3) based
on three accelerometers, will also be
installed on the two heavy freight cargo
vessels. With this, multiple critical loca-
tions of
the ves-
sel, for
instance
the cargo,
can be
measured
and
ROVs clean hulls
CleanHull Singapore Pte Ltd.
successfully performed the first
environmental-friendly hull clean-
ing test trial at a Singapore port
terminal using ROVs. Through close
collaboration with maritime com-
panies, and as part of the memo-
randum of understanding signed
in April 2012 between the Maritime
and Port Authority of Singapore
(MPA), the Singapore Maritime
Institute, and BW Ventures Pte Ltd,
hull cleaning technology was de-
ployed by a local team from Clean-
Hull. On-site testing confirmed
the feasibility of performing hull
cleanings of container ships and
other vessels during their loading
and unloading activities at the port
terminals in Singapore. By using an ROV or even multiple ROVs simultaneously for
hull cleanings, instead of deploying divers, provides a safe and reliable choice that
is independent of water visibility, currents, time of the day, and ongoing activities on
the vessel (such as loading/unloading/bunkering). In addition, the collection and
filtering systems assure that residues and potential contaminants can be disposed
of through environmentally-friendly procedures and without harm to marine life and
water quality at the port.
www.cleanhull.no
AOG
|
September
·
October 2014
22
aogdigital.com
Cleanhull ROV deployed in Singapore.
Photo from BW Maritime.
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Spotlight
engineering and structural mechanics at
the University of California at Berkeley
in 1978 as a Fulbright Scholar. He later
joined the AIT staff, serving as a
professor since 1987. In administration,
he has served as the dean of the former
School of Civil Engineering 1998-2004,
as founding dean of School of Engineer-
ing and Technology 2004-2009, as Vice
President for Resource Development
2009-2013, and as Interim president
since 13 February 2013.
The UK-based
Energy Industries
Council (EIC) named
Azman Nasir
the
EIC’s new head of
Asia Pacific. Nasir,
who has 24 years’
experience in the
transport, railway, oil and gas, and
marine industry sectors, will be based
out of the EIC’s new Kuala Lumpur
office, which has been recently relocated
from Singapore. Nasir will be respon-
sible for supporting the EIC’s member-
ship base and growing the EIC’s
activities across Asia Pacific, Austral-
asia, China, the Indian Sub-Continent,
Afghanistan and Pakistan. Nasir was
previously general manager of a project
management company responsible for
developing Malaysia’s railway infra-
structure and was CEO of Malaysia’s
Labuan Shipyard & Engineering for
three years.
“We are delighted to be welcoming
Azman to the EIC at a time of grow-
ing UK company activity within both
Malaysia and Asia as a whole,” said
the EIC’s Chief Executive Officer Claire
Miller. “Azman’s industry experience
and local knowledge will be invaluable
to the EIC’s membership as they look
to capitalize on opportunities in these
growing Asian markets.”
Of his appointment, Azman Nasir
said: “It’s clear that many UK companies
today are looking east to do business
as the onshore and offshore oil & gas,
power and renewable sectors all con-
tinue to grow. The EIC will remain at
the forefront of these developments, un-
locking opportunities for our members
and helping them to win business across
this vast and highly profitable region.”
Newly established
exploration and
production com-
pany, Singapore-
based AziPac Ltd.,
named
Frank
Inouye
its new
managing director.
Inouye has over 34 years’ experience in
the oil and gas industry. He has worked
extensively in Australia, Asia, North
Africa, Canada and South America. Dur-
ing his career, Inouye held several
senior management positions including;
executive chairman, CEO/COO of
Coastal Energy, a company he founded
in 2004 and led until 2008. It was sold to
Cepsa for US$2.2 billion in 2013; CEO of
Samudra Energy; head of corporate
development for Premier Oil and general
manager of Premier’s southeast Asian
operations.
AOG
US-based project
management
company Crowley
Maritime chose
William Hill
to serve
as manager for its
new Singapore office.
Hill previously
served as director, business develop-
ment, for Crowley’s Anchorage, Alaska,
office for the last six years where he
worked numerous sealift and marine
projects for major oil, gas, and engineer-
ing, construction and procurement
management customers. “We’ve seen an
increase in customers requiring service
in the (Asia Pacific) region and as part of
our commitment to consistently evaluate
and expand service offerings to meet
such needs, we decided that a physical
location with local personnel in
Singapore was necessary,” Hill said. “It
will allow us to not only have in-person
management of our assets in the area,
but will also provide better, more timely
communication with our current and
potential customer base.”
Worsak Kanok-
Nukulchai
has been
named the seventh
president of the
Asian Institute of
Technology (AIT) in
Pathumthani,
Thailand. He is the
first AIT alumnus, the first Asian, and
the first Thai national to be selected as
president of AIT in its 54-year history.
He earned his Ph.D. in structural
Wild Well Control, Inc., appointed
Wayne Stennes
and
Christian Haustead
managing director and area manager, respectively, at the company’s regional
office in Kuala Lumpur, Malaysia. Stennes and Haustead will enhance emer-
gency well control operations and assist market development for non-emer-
gency well control engineering services. “The addition of Wayne Stennes and
Christian Haustead will greatly enhance Wild Well’s response and engineering
capabilities for our clients throughout the Asia Pacific region,” said Freddy
Gebhardt, president of Wild Well Control. “Wayne and Christian both bring
a wealth of knowledge regarding the emergency response processes required
when dealing with emergency well control incidents. Their experience in this
field will provide our clients with the most comprehensive and heightened
level of response to a well control emergency, onshore and offshore.”
Wayne StennesChristian Haustead
September
·
October 2014
|
AOG
23
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|
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·
October 2014
24
aogdigital.com
US$
13.6
million
s e comne capacy o ree
GE-backed Atria Power wind projects,
ocae n na. ee page .
300,000
A conventional semisubmersible rig is held together by 300,000
bolted joints. See page 22.
The amount of money CNPC has
agreed to reimburse the Myanmar
government as rent for its crude oil
pipeline. See page 16.
990
bcf
Australia exported about 990Bcf of
LNG in 2012. See page 10
.
Opus Offshore’s new Tiger and Tiger
II drillships will be able to drill to
32,9000ft. See page 6
.
32,900
ft
is the size of the Wassana oil field, located in Thailand’s Pattani
basin. See page 5.
4696
sq km
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September/October 2014
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Association (NOIA)
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Direct: 713.874.2202 | Cell: 832.544.5891
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and participate in the Mooring Special
Session Workshop held on September 23
rd
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September 23 – 25, 2014
4
th
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Galveston Island Convention Center
at
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today!
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