Petronas makes deepwater oil and gas discovery off Gabon


Offshore staff

KUALA LUMPUR, Malaysia – Petronas subsidiary PC Gabon Upstream S.A. (PCGUSA) has discovered oil and gas with the Boudji-1 well in block F14 (Likuale) offshore southern Gabon.

The exploration, drilling in 2,800 m (9,186 ft) of water, encountered 90 m (295 ft) of gross high-quality hydrocarbon-bearing presalt sands.

The company and the Ministry of Petroleum & Hydrocarbons will conduct an assessment to further determine the commerciality of the resource volume.

PCGUSA is the operator of block F14 (Likuale), with Woodside holding a 30% participating interest.

Executive Vice President & Upstream CEO Datuk Mohd Anuar Taib said: “The discovery in Gabon is an encouraging development for Petronas, as we continue to pursue growth activities beyond Malaysia, in line with the strategy to expand our core oil and gas business by growing our resource base.”

“Aside from boosting Gabon’s oil and gas industry, this discovery will also spur further growth activities in the region, and complements our achievements towards building a significant deepwater portfolio globally,” he added.


Petronas discovers oil and gas offshore Gabon

KUCHING: PC GAbon Upstream SA (PCGUSA), a subsidiary of Petroliam Nasional Bhd (Petronas), has discovered oil and gas at its Boudji-1 exploration well in Block F14 (Likuale), South Gabon.

Petronas in a statement yesterday said said the discovery marked a significant milestone as Petronas continues to expand upstream growth in West Africa, and demonstrated frontier exploration and deepwater operational capabilities.

“It is an encouraging development for Petronas, as we continue to pursue growth activities beyond Malaysia, in line with the strategy to expand our core oil and gas business by growing our resource base,” executive vice president and upstream chief executive officer, Datuk Mohd Anuar Taib said.

The ultra-deepwater exploration well, drilled in water depths of 2,800 metres, encountered 90 metres of gross high-quality hydrocarbon-bearing pre-salt sands.

“Aside from boosting Gabon’s oil and gas industry, this discovery will also spur further growth activities in the region, and complements Petronas’ achievements towards building a significant deepwater portfolio globally,” said Mohd Anuar.

Petronas and Gabon’s Ministry of Petroleum & Hydrocarbons would be conducting an assessment to further determine the commerciality of the resource volume.

PCGUSA is the operator for Block F14 (Likuale), with Australia’s Woodside holding a 30 per cent participating interest.

To date, Petronas’ deepwater portfolio includes partnerships in the Gumusut-Kakap, Malikai and Kikeh deepwater fields located offshore Sabah.

Additionally, there would be two new upcoming deepwater development projects in the portfolio, namely the Limbayong field in Sabah and Kelidang Cluster in Brunei.

Petronas said its global upstream reach continued to expand in Mexico after winning six deepwater blocks in bidding round 2.4. This has positioned the company as the second largest gross acreage holder in offshore Mexico with a total of nine blocks.

“Further strengthening the company’s presence in West Africa, Petronas has recently signed a farm-out agreement (FOA) with Australia’ FAR Ltd for a 40 per cent interest in the offshore petroleum licenses of Blocks A2 and A5 located offshore Gambia,” it added.


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Shell sees potential LNG supply shortage as global demand surges

February 26, 2018
Source: Shell
The global liquefied natural gas (LNG) market has continued to defy expectations of many market observers, with demand growing by 29 million tonnes to 293 million tonnes in 2017, according to Shell’s annual LNG Outlook. Such strong growth in demand is consistent with Shell’s first LNG Outlook, published in 2017. Based on current demand projections, Shell sees potential for a supply shortage developing in mid-2020s, unless new LNG production project commitments are made soon.

Japan remained the world’s largest LNG importer in 2017, while China moved into second place as Chinese imports surged past South Korea’s. Total demand for LNG in China reached 38 million tonnes, a result of continued economic growth and policies to reduce local air pollution through coal-to-gas switching.

“We are still seeing significant demand from traditional importers in Asia and Europe, but we are also seeing LNG provide flexible, reliable and cleaner energy supply for other countries around the world,” said Maarten Wetselaar, Integrated Gas and New Energies Director at Shell. “In Asia alone, demand rose by 17 million tonnes. That’s nearly as much as Indonesia, the world’s fifth-largest LNG exporter, produced in 2017.”

LNG has played an increasing role in the global energy system over the last few decades. Since 2000, the number of countries importing LNG has quadrupled and the number of countries supplying it has almost doubled. LNG trade increased from 100 million tonnes in 2000 to nearly 300 million tonnes in 2017. That’s enough gas to generate power for around 575 million homes.

LNG buyers continued to sign shorter and smaller contracts. In 2017, the number of LNG spot cargoes sold reached 1,100 for the first time, equivalent to three cargoes delivered every day. This growth mostly came from new supply from Australia and the USA.

The mismatch in requirements between buyers and suppliers is growing. Most suppliers still seek long-term LNG sales to secure financing. But LNG buyers increasingly want shorter, smaller and more flexible contracts so they can better compete in their own downstream power and gas markets.

This mismatch needs to be resolved to enable LNG project developers to make final investment decisions that are needed to ensure there is enough future supply of this cleaner-burning fuel for the world economy.

See Shell’s full LNG Outlook for 2018 here.

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KrisEnergy to extract Cambodia’s first oil in 2019

By: Euan Black – POSTED ON: October 20, 2017

The Singaporean company has taken a significant step towards producing Cambodia’s first ever barrel of oil

Kelvin Tang (C), president of KrisEnergy Cambodia, Malaysian Tan Ek Kia (L), chairman of the KrisEnergy Group, and Aun Pornmoniroth (R), Cambodian minister of economy and finance, toast during a signing ceremony in Phnom Penh, Cambodia, 23 August 2017. Photo: EPA/Mak Remissa

KrisEnergy, the Singaporean oil and gas company that operates Cambodia’s offshore Block A in the Gulf of Thailand, has announced that it has reached a final investment decision (FID) “to proceed with the first phase of development for the Apsara oil field”, and expects to begin oil production in 2019.

“FID is another step in progressing the Apsara development within the target timeframe following the formal signing of the petroleum agreement in late August,” Kelvin Tang, KrisEnergy’s chief executive officer, said in a statement, adding that the next stage for KrisEnergy was to source materials, equipment and services.

Once the structure that will house the equipment used to extract the oil has been built, it will be towed out to the field, secured in place and connected to a moored production barge, which KrisEnergy believes will be capable of processing and separating up to 30,000 barrels of fluid per day.

According to Adrian Pooh, a senior analyst at global renewables and energy consultancy WoodMackenzie, KrisEnergy’s announcement marks the beginning of an intense and costly two-year preparation process.

“The development requires significant capital investment, which we estimate at around $145-150m between 2018 and 2020,” he told Southeast Asia Globe.

“Depending on the results from developing Apsara Phase 1A, there is scope for additional phases to extract pockets of resources, much like the gulf of Thailand, where KrisEnergy has much experience. We estimate 8.6 million barrels of recoverable reserves for Phase 1A.”

KrisEnergy purchased their stake in Block A from Chevron in 2014 – ten years after the US oil giants first discovered the Apsara oil field – amid a global slump in oil prices and suggestions of a breakdown in relations between Chevron and the Cambodian government.

According to a 2009 Global Witness report, Chevron had been forced to pay an unreasonable “signature bonus” to the Cambodian National Petroleum Authority – an institution answerable only to Prime Minister Hun Sen.

While the price of oil dropped to a low of $29 per barrel in January 2016, last month it rebounded to a two-year high of $59, an upswing in part caused by Turkish President Recep Tayyip Erdogan’s threat to turn off an Iraqi oil pipeline in response to the country’s Kurdish population recently voting for independence.

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Petronas says second floating LNG facility to be operational in 2020

Reuters Staff

KUALA LUMPUR (Reuters) – Malaysian state-owned oil firm Petroliam Nasional Bhd said on Sunday its second floating liquefied natural gas (LNG) facility will be operational in 2020.

Petronas loaded its first cargo from the Petronas Floating LNG (PFLNG) 1 in east Malaysia last month, becoming the first company to produce LNG from a floating production unit.

The second one that is under construction, PFLNG 2, will enable liquefaction, production and offloading of natural gas in the Rotan field, 240 kilometers off the east Malaysian state of Sabah upon completion. It is set to have a processing capacity of 1.5 million tonnes per annum (mtpa).

Adnan Zainal Abidin, Petronas’ acting vice president LNG assets, development and production, said development of the second facility was on track and that the company has received interest from other industry players for using both the facilities.

“We are in discussions with a number of third parties who are interested to have our floaters at their locations,” Adnan told reporters ahead of the Asia Oil and Gas Conference in Kuala Lumpur. “It could be the use of existing or new floaters.”

Adnan said the costs of the second facility will be lower than the first floater, though he declined to disclose the cost of the development.

PFLNG 1 will reach its designed capacity of 1.2 mtpa by June, and will be stationed at Kanowit in East Malaysia for five years, said chief executive of PFLNG Feisal Azhar.

Other producers currently developing floating LNG production facilities include Royal Dutch Shell, who is building the Prelude FLNG project in Australia which will be the world’s biggest maritime vessel at a cost of over $12 billion.

Japan’s Inpex is building a similarly big FLNG unit as part of the $37 billion Ichthys export project, also for use in Australia.

But both of these expensive projects have been plagued by delays and a global supply glut as new LNG projects come online in Australia and the United States. The huge development costs have led some to question whether FLNG units on this scale will be ordered again in future.

Petronas’ Adnan said Asia will still be a huge customer for LNG.

He said new markets like India are huge for LNG demand, while Thailand was also buying more LNG, adding that the first cargo from PFLNG 1 went to India.

Reporting by Emily Chow, A. Ananthalakshmi and Florence Tan; Editing by Christian Schmollinger

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North Malay Basin platforms deliver first gas


Offshore staff

NEW YORK – Gas production has started from the Hess-operated North Malay Basin full-field development in the Gulf of Thailand, following hookup of the topsides for the central processing platform.

Commissioning activities continue.

Hess expects its net production to ramp up shortly to around 165 MMcf/d.

North Malay Basin comprises nine gas fields in block PM302 with combined recoverable reserves of over 1.5 tcf of gas and over 20 MMbbl of condensate.

The location is roughly 186 mi (300 km) offshore the Trengganu Gas Terminal in a water depth of round 180 ft (55 m), with multiple gas bearing zones located at depths of 3,500-10,000 ft (1,000-3,000 m).

Hess operates with a 50% interest, in partnership with Petronas Carigali with the other 50%. The two also collaborate in the adjacent block A-18 in the Malaysia-Thailand Joint Development Area (JDA).

The North Malay Basin full-field development project benefits from a strong and long-term Petronas-Hess relationship and leverages experience gained from other projects within the JDA.

Development involved installation of four wellhead platforms, aside from the central processing platform, intra-field and export pipelines and associated subsea isolation valve skids, a moored floating storage and offloading unit and drilling of 14 shallow production wells.



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Shell scraps sale of $900m Thai gas field stake to KUFPEC

EBR Staff Writer

Published 04 October 2017

Royal Dutch Shell has scrapped its $900m deal to divest its stake in the Bongkot gas and condense field in Thailand to a subsidiary of Kuwait Foreign Petroleum Exploration Company (KUFPEC).

The parties associated with the sale and purchase agreement made in January had reached a mutual understanding to terminate it.

Shell and KUFPEC failed to resolve the different interpretations they had on the share sale transactions within the committed timeframe. This, eventually led to the cancellation of the agreement, reports Reuters citing an emailed statement from a Shell representative.

As part of the deal, Kufpec Thailand was to acquire a stake of 22.2% from Shell Integrated Gas Thailand (SIGT) and Thai Energy (TEC), both subsidiaries of Shell. The stake was related to the Bongkot field and adjoining acreage in Thai waters comprising Blocks 15, 16 and 17 and block G12/48.

Currently, Shell’s partners in the Bongkot field are PTT Exploration & Production (PTTEP) which is the operator with a stake of 44.4% and Total with 33.3% stake.

According to Shell, its subsidiaries SIGT and TEC will continue to support the state-owned oil and gas firm PTTEP in the safe and efficient operation and additional development of the gas field.

The oil giant also revealed that SIGT plans to take part in the upcoming licensing round for the extension of the Bongkot field.

Shell stated: “Shell Group’s divestment programme continues to make good progress at both raising cash and re-shaping the company.

“To date, the company has more than $25 billion in completed, announced or in progress divestments, on track to meet its target of $30 billion of divestments between 2016 and 2018.”

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PETRONAS to award maintenance jobs soon

Jose Barrock / The Edge Malaysia

September 25, 2017 15:00 PM MYT

This article first appeared in The Edge Malaysia Weekly, on September 18, 2017 – September 24, 2017

PETROLIAM Nasional Bhd (Petronas) is understood to have conducted a pre-award meeting for its maintenance, construction and modification (MCM) jobs, which translate into contracts collectively worth RM6 billion, sources say.

This means the long wait for the award of these contracts — valued at close to RM1 billion each — will soon be over.

“We had the pre-award meeting about a week ago, so the actual awarding should be soon,” says a source.

Another industry source says Petronas has divided the contracts for oil and gas platform maintenance. The earlier notion was that the national oil company would split the MCM jobs into six packages for a five-year duration but this is not certain yet.

It is understood that several bidders have been dropped and that it is the “usual suspects” that have won the lion’s share of the jobs.

The “usual suspects” include Dayang Enterprise Holdings Bhd, Petra Energy Bhd, Sapura Energy Bhd’s wholly owned SapuraKencana Pinewell Sdn Bhd, Carimin Petroleum Bhd, Deleum Bhd, Icon Offshore Bhd and privately held Borneo Sea Offshore Engineering Sdn Bhd.

Deleum and Icon are understood to have some form of tie-up on the operating level but not any formal joint venture.

While details are scarce, Dayang is understood to have bagged the contract to maintain oil platforms in Sarawak while Sapura is understood to have won the gas portion in the state. Deleum is said to have bagged a substantial contract in Peninsular Malaysia.

The integrated logistics contracts are slated to be awarded soon as well, although no details were available at press time.

News of the award of MCM contracts by Petronas augurs well for the domestic oil and gas industry, whose many players are still struggling to survive in the current low oil price environment.

Many felt the heat when the national oil company initiated the renegotiation of contract terms when crude oil prices collapsed in October 2014, and followed it with job cuts.

The MCM contracts will be timely for oil and gas players who can now replenish their order books, which has been a challenging task across the board.

Crude oil prices seem to have stabilised at between US$45 and US$55 per barrel. Concerns about a glut surfaced in June when crude oil dipped below US$45, thanks to some countries ramping up production after prices rose. Nonetheless, prices have rebounded from a low of US$44.82, the lowest level since November last year.

Analysts feel price stability is what counts whether crude oil is low at US$40 or high at US$100 per barrel. In the past, oil majors were cautious about capital expenditure partly due to the volatility.

Some oil majors are expected to increase their capital expenditure after they had slashed it for more than two years. Analysts see activity picking up in the sector with the demand for services expected to be high, although it would not be as robust when oil was trading at more than US$100 per barrel.

In June, UMW Oil & Gas Bhd was awarded two contracts with a combined estimated worth of US$34.81 million (about RM151.08 million) by Petronas Carigali Sdn Bhd. UMWOG will provide two jack-up drilling rigs to support Petronas Carigali’s offshore upstream projects.

In April, Malaysia Marine and Heavy Engineering Holdings Bhd won a RM1 billion contract for the central processing platform (CPP) in Petronas’ Bokor Phase 3 redevelopment project. The contract was awarded by Petronas Carigali.

Nonetheless, some industry players say the bigger concern could be obtaining financing as banks have become very cautious about giving loans to oil and gas-related companies after the oil price slump.


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