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Last Updated: October 20, 2017
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Last week in World oil:

Prices

  • Crude prices remain stuck in their range – Brent at US$57/b and WTI at US$51/b – as swings in US inventories outweigh Middle Eastern geopolitical concerns, with little on to horizon to move the market. 

Upstream

  • Chinese major Sinopec is planning to exit Argentina, after losses and labour woes prompted it to put its oil assets on sale. Acquired in 2010 from Occidental Petroleum for US$2.45 billion, the acquisition was part of Sinopec’s drive to establish a portfolio of international upstream assets. However, a shaky political and economic situation in Argentina caused losses, and the oil and gas assets – mainly in the southern province of Santa Cruz – now have a price estimate of US$750 million-1 billion.
  • Uganda is quickly becoming a potential new African upstream bright spot, with Nigeria’s Oranto Petroleum recently signing two PSCs to explore around the Lake Albert basin. The Ngassa Shallow Play and Ngassa Deep Play are located within the Albertine rift basin where Uganda first struck oil in 2006; Uganda’s first domestic oil is expected in 2020.
  • Cote d’Ivoire has concluded four PSCs with Tullow Oil in a bid to jumpstart its fledgling upstream industry. Producing a mere 8 kb/d of oil and 200 mcf/d of gas, Cote d’Ivoire lags behind Senegal and Ghana, but is hoping that recent big finds in its neighbours hint at potential within its waters. State oil firm Petroci will hold 10% of each PSC.
  • US drillers cut active rig counts for the fourth time in five weeks, as price realities impact production plans. Eight rigs were removed from service last week – five oil and three gas – leaving the total active count at 928.

Downstream & Midstream

  • Another international joins the queue to exploit Mexico’s recently deregulated fuel retail industry, joining Shell, BP, ExxonMobil and Glencore. France’s Total is expanding its downstream presence in Mexico from specialty products to a full service station network, rebranding some 250 Mexico City-area GASORED group sites to the Total brand. The first site will be opened in late 2017, rolling out over 2018 and 2019. 

Natural Gas and LNG

  • More LNG this way comes. A week after Chevron began operations at Wheatstone, Russia’s Yamal LNG project in the Arctic confirmed that it will ship its first LNG cargo in November. Operated by Russia’s Novatek with France’s Total, China’s CNPC and the Silk Road Fund, Yamal will begin with two shipments in November, four in December, then ramp up to ten in 2018. The first cargoes were reportedly sold on the spot market.

Corporate

  • Indications are the Saudi Aramco’s planned IPO has hit some snags. Recent reports indicate that some delays are expected, with a two-stage IPO likely – floating in Riyadh by the end of 2018 and delaying the planned international portion until 2019. Some chatter on the market even suggests that Aramco may scrap the international portion altogether, replacing with a private share sale to select world sovereign funds and institutional investors.

Last week in Asian oil

Upstream

  • Malaysia’s Petronas has outlined its plans for the Bukit Tua field in Indonesia. Phase one of Bukit Tua came on stream in May 2015; phase two is currently underway and Petronas wants to expand into a phase three that will exploit the field’s Kujung horizon. Expansions will continue through July 2022, lifting production from its current peak rate of 20 kb/d of oil and 50 mmscf/d of gas. Petronas holds 80% of the PSC, with the remainder held by Pertamina.

Downstream & Midstream

  • CNOOC’s 200 kb/d refinery in Huizhou is ready for commissioning. Crude trial runs have been completed at the site in Guangdong, which is part of CNOOC’s Huizhou refining and petrochemical complex that represents the firm’s move downstream to compete with Sinopec and PetroChina. The focus of the complex is for both fuels and chemicals, with a 1.2 mtpa ethylene plant (a joint venture with Shell) due to be completed in Q12018.
  • From a loose and scrappy group, China’s independent refiners – the teapots – are increasing becoming more structured and united, as they face increasing criticism from Sinopec and PetroChina. After forming a crude buying alliance last year, six influential teapots – including Dongming, the country’s largest independent refiner – set up the Shandong Refining & Chemical Group last month, and has now bolstered it with a CNY33 billion (US$5 billion) fund. The joint fund will go to joint production, operation and investment plans, as well as lobbying efforts, to support the group’s refining capacity of 660 kb/d.
  • Once dismissed as a pipe dream, the private Pulau Muara Besar refinery planned by Hengyi Petrochemical in Brunei actually appears to be progressing to reality. The Chinese group has started up a trading office in Singapore, which will buy crude and trade fuel products produced at the 175 kb/d, US$3.4 billion project. Primarily a petrochemical play to support Hengyi’s fabric and industrial arms, the refinery will also produce a significant amount of gasoline, gasoil and jet fuel, which Hengyi has no internal use for. The company has also announced a US$12 billion second phase that will include expanding capacity to 280 kb/d and secondary units to produce some 1.5 mtpa of ethylene and 2 mtpa of PX.

Natural Gas & LNG

  • Bangladesh is striving ahead in its LNG ambitions, signing up for a third floating LNG project with Malaysia’s Petronas and China’s Hong Kong Manjala Power. Planned to be located at Kutubdia in Cox’s Bazaar, the 3.5 mtpa import terminal is planned for a 2019 start, just in time to replace Bangladesh’s dwindling natural gas production. The country’s first FSRU – a 3.75 mtpa facility off Moheshkhali in the Bay of Bengal – is expected to start up in 2018.
  • CNPC has started up its third natural gas pipeline servicing Shanghai, aiming to meet the growing demand for clean power generation fuel in the city. The new 88km pipeline connects the Rudong LNG receiving terminal in Jiangshu with Shanghai’s Chongming island, with a capacity of some 1.84 billion cbm per year.

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BP & The Expansion of the Caspian

The vast Shah Deniz field in Azerbaijan’s portion of the South Caspian Sea marked several milestones in 2018. It has now produced a cumulative total of 100 billion cubic metres of natural gas since the field started up in 2006, with daily output reaching a new peak, growing by 12.5% y-o-y. At a cost of US$28 billion, Shah Deniz – with its estimated 1.2 trillion cubic metres of gas resources – has proven to be an unparalleled success, being a founding link of Europe’s Southern Gas Corridor and coming in relatively on budget and on time. And now BP, along with its partners, is hoping to replicate that success with an ambitious exploration schedule over the next two years.

Four new exploration wells in three blocks, along with a seismic survey of a fourth, are planned for 2019 and an additional three wells in 2020. The aggressive programme is aimed at confirming a long-held belief by BP and SOCAR there are more significant pockets of gas swirling around the area. The first exploratory well is targeting the Shafag-Asiman block, where initial seismic surveys suggest natural gas reserves of some 500 billion cubic metres; if confirmed, that would make it the second-largest gas field ever discovered in the Caspian, behind only Shah Deniz. BP also suspects that Shah Deniz itself could be bigger than expected – the company has long predicted the existence of a second, deeper reservoir below the existing field, and a ‘further assessment’ is planned for 2020 to get to the bottom of the case, so to speak.

Two wells are planned to be drilled in the Shallow Water Absheron Peninsula (SWAP) block, some 30km southeast of Baku, where BP operates in equal partnership with SOCAR, with an additional well planned for 2020. The goal at SWAP is light crude oil, as is a seismic survey in the deepwater Caspian Sea Block D230 where a ‘significant amount’ of oil is expected. Exploration in the onshore Gobustan block, an inland field 50km north of Baku, rounds up BP’s upstream programme and the company expects that at least one seven wells of these will yield a bonanza that will take Azerbaijan’s reserves well into the middle of the century.

Developments in the Caspian are key, as it is the starting node of the Southern Gas Corridor – meant to deliver gas to Europe. Shah Deniz gas currently makes its way to Turkey via the South Caucasus Gas pipeline and exports onwards to Europe should begin when the US$8.5 billion, 32 bcm/y Trans-Anatolian Pipeline (TANAP) starts service in 2020. Planned output from Azerbaijan currently only fills half of the TANAP capacity, meaning there is room for plenty more gas, if BP can find it. From Turkey, Azeri gas will link up to the Trans-Adriatic Pipeline in Greece and connect into Turkey, potentially joined by other pipelines projects that are planned to link up with gas production in Israel. This alternate source of natural gas for Europe is crucial, particularly since political will to push through the Nordstream-2 pipeline connecting Russian gas to Germany is slackening. The demand is there and so is the infrastructure. And now BP will be spending the next two years trying to prove that the supply exists underneath Azerbaijan.

BP’s upcoming planned exploration in the Caspian:

  • Shafag-Asiman, late 2019, targeting natural gas
  • SWAP, 3 sites, late 2019/2020, targeting oil
  • ‘Onshore gas project’, end 2019, targeting natural gas’
  • Block D230, 2019 (seismic assessment)/2020 (drilling), targeting oil
  • Shah Deniz ‘further assessment’, 2020, targeting natural gas
January, 22 2019
RAPID Rises

When it was first announced in 2012, there was scepticism about whether or not Petronas’ RAPID refinery in Johor was destined for reality or cancellation. It came at a time when the refining industry saw multiple ambitious, sometimes unpractical, projects announced. At that point, Petronas – though one of the most respected state oil firms – was still seen as more of an upstream player internationally. Its downstream forays were largely confined to its home base Malaysia and specialty chemicals, as well as a surprising venture into South African through Engen. Its refineries, too, were relatively small. So the announcement that Petronas was planning essentially, its own Jamnagar, promoted some pessimism. Could it succeed?

It has. The RAPID refinery – part of a larger plan to turn the Pengerang district in southern Johor into an oil refining and storage hub capitalising on linkages with Singapore – received its first cargo of crude oil for testing in September 2018. Mechanical completion was achieved on November 29 and all critical units have begun commissioning ahead of the expected firing up of RAPID’s 300 kb/d CDU later this month. A second cargo of 2 million barrels of Saudi crude arrived at RAPID last week. It seems like it’s all systems go for RAPID. But it wasn’t always so clear cut. Financing difficulties – and the 2015 crude oil price crash – put the US$27 billion project on shaky ground for a while, and it was only when Saudi Aramco swooped in to purchase a US$7 billion stake in the project that it started coalescing. Petronas had been courting Aramco since the start of the project, mainly as a crude provider, but having the Saudi giant on board was the final step towards FID. It guaranteed a stable supply of crude for Petronas; and for Aramco, RAPID gave it a foothold in a major global refining hub area as part of its strategy to expand downstream.

But RAPID will be entering into a market quite different than when it was first announced. In 2012, demand for fuel products was concentrated on light distillates; in 2019, that focus has changed. Impending new International Maritime Organisation (IMO) regulations are requiring shippers to switch from burning cheap (and dirty) fuel oil to using cleaner middle distillate gasoils. This plays well into complex refineries like RAPID, specialising in cracking heavy and medium Arabian crude into valuable products. But the issue is that Asia and the rest of the world is currently swamped with gasoline. A whole host of new Asian refineries – the latest being the 200 kb/d Nghi Son in Vietnam – have contributed to growing volumes of gasoline with no home in Asia. Gasoline refining margins in Singapore have taken a hit, falling into negative territory for the first time in seven years. Adding RAPID to the equation places more pressure on gasoline margins, even though margins for middle distillates are still very healthy. And with three other large Asian refinery projects scheduled to come online in 2019 – one in Brunei and two in China – that glut will only grow.

The safety valve for RAPID (and indeed the other refineries due this year) is that they have been planned with deep petrochemicals integration, using naphtha produced from the refinery portion. RAPID itself is planned to have capacity of 3 million tpa of ethylene, propylene and other olefins – still a lucrative market that justifies the mega-investment. But it will be at least two years before RAPID’s petrochemicals portion will be ready to start up, and when it does, it’ll face the same set of challenging circumstances as refineries like Hengli’s 400 kb/d Dalian Changxing plant also bring online their petchem operations. But that is a problem for the future and for now, RAPID is first out of the gate into reality. It won’t be entering in a bonanza fuels market as predicted in 2012, but there is still space in the market for RAPID – and a few other like in – at least for now.

 

RAPID Refinery Factsheet:

  • Ownership: Petronas (50%), Saudi Aramco (50%)
  • Capacity: 300 kb/d CDU/3 mtpa olefins plant
  • Other facilities: 1.22 Gigawatt congeneration plant, 3.5 mtpa regasification terminal
  • Expected commissioning: March 2019
January, 21 2019
Forecasting Bangladesh Tyre Market | Zulker Naeen

Tyre market in Bangladesh is forecasted to grow at over 9% until 2020 on the back of growth in automobile sales, advancements in public infrastructure, and development-seeking government policies.

The government has emphasized on the road infrastructure of the country, which has been instrumental in driving vehicle sales in the country.

The tyre market reached Tk 4,750 crore last year, up from about Tk 4,000 crore in 2017, according to market insiders.

The commercial vehicle tyre segment dominates this industry with around 80% of the market share. At least 1.5 lakh pieces of tyres in the segment were sold in 2018.

In the commercial vehicle tyre segment, the MRF's market share is 30%. Apollo controls 5% of the segment, Birla 10%, CEAT 3%, and Hankook 1%. The rest 51% is controlled by non-branded Chinese tyres.

However, Bangladesh mostly lacks in tyre manufacturing setups, which leads to tyre imports from other countries as the only feasible option to meet the demand. The company largely imports tyre from China, India, Indonesia, Thailand and Japan.

Automobile and tyre sales in Bangladesh are expected to grow with the rising in purchasing power of people as well as growing investments and joint ventures of foreign market players. The country might become the exporting destination for global tyre manufacturers.

Several global tyre giants have also expressed interest in making significant investments by setting up their manufacturing units in the country.

This reflects an opportunity for local companies to set up an indigenous manufacturing base in Bangladesh and also enables foreign players to set up their localized production facilities to capture a significant market.

It can be said that, the rise in automobile sales, improvement in public infrastructure, and growth in purchasing power to drive the tyre market over the next five years.

January, 18 2019