Monday, September 14, 2015

Lack of ‘crude’ conclusions from Chinese equities

As another week starts with both Brent and WTI futures trading lower, concerns about China which aren’t new, continue to be brandished about. What the Oilholic does not understand is the overt obsession in certain quarters with the direction of Chinese equities.

The country’s factory gate prices and purchasing managers’ indices haven’t exactly impressed over the last few months. Yet, somehow a stock market decline spooks most despite both the mechanism as well as the market itself lacking maturity. It is also constantly prone to government interference and crackdowns on trading firms.

On one level the anxiety is understandable; the Shanghai Composite Index – lurking just around 3,080-level at the time of writing this blog post – has lost nearly 39.5% since its peak in mid-June. However, it does not tell the full story of China’s economy and the correction it is currently undergoing, let alone its ambiguous connect with the country’s oil imports.

The sign of any mature stock market – for example London or Frankfurt – is that the total tradable value of equities listed is 100% (or above) of the country’s Gross Domestic Product. In Shanghai’s case, the figure is more in the region of 34%, suggesting it still has some way to go.

A mere 2.1% of Chinese equities are under foreign ownership at the moment. Many of the country’s major companies, including oil and gas firms, have dual listings in Hong Kong or New York, which while not an indication of lack of domestic faith, is more of an acknowledgement of impact making secondary listings away from home.

Mark Williams, Chief Asia Economist at Capital Economics, feels panic over China is overblown. “The debacle in China’s equity market tells us little directly about what is going on in China’s economy. The surge in prices that started a year ago was speculative, rather than driven by any improvement in fundamentals. A combination of poor data and policy inaction in China may have triggered recent market falls but the bigger picture is that we are witnessing the inevitable implosion of an equity market bubble,” he said.

Furthermore, current turmoil does not provide any direction whatsoever on what the needs of the economy would be in terms of oil imports. Apart from a blip in May, China has continued to import oil at the rate of 7 million barrels per day for much of this year. That’s not to say, all of it is for domestic consumption. 

Some of it also goes towards strategic storage, data on which is rarely published and a substantial chunk goes towards the country’s export focussed refineries. China remains a major regional exporter of refined products.

Admittedly, much of the commodities market should be worried if not panicking. Over the years, China consumed approximately half of the world’s iron ore, 48% of aluminium, 46% of zinc and 45% of copper. Such levels of consumption could never have been sustained forever and appear to be unravelling. 

Williams noted: “To some extent, China’s recent pattern of weakness in property construction and heavy industry set against strength in services is a positive sign that rebalancing towards a more sustainable growth model is underway. Policymakers in China, unlike their counterparts in many developed economies, still have room to loosen policy substantially further.”

While China’s declining demand is of concern, chronic oversupply in the case of a whole host of commodities – including oil – cannot be ignored either. The current commodities market downturn in general, and the oil price decline in particular, remains a story of oversupply not necessarily a lack of demand.

Another more important worry, as the Oilholic noted via a column on Forbes, is the possibility of a US interest rate hike. The Federal Reserve will raise interest rates; it might not be soon (i.e. this month) but a move is on the horizon. This will not only weigh on commodities priced in dollars, but has other implications for emerging markets with dollar denominated debt at state, individual and institutional levels; something they haven’t factored into their thinking for a while.

In summation, there is a lot to worry about for oil markets, rather than fret about where the Shanghai Composite is or isn’t going. That’s all for the moment folks! Keep reading, keep it ‘crude’!

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© Gaurav Sharma 2015. Photo: Shanghai Stock Exchange, Shanghai, China © Gaurav Sharma, August 2014.

Wednesday, September 02, 2015

Grappling with volatility in a barmy crude market

The oil market is not making a whole lot of sense at present to a whole lot of people; the Oilholic is admittedly one of them. However, wherever you apportion the blame for the current market volatility, do not take the convenient route of laying it all at China’s doorstep. That would be oversimplification!

It is safe to say this blogger hasn’t seen anything quite as barmy over the last decade, not even during the post Lehman Brothers kerfuffle as a US financial crisis morphed into a global one. That was in the main a crisis of demand, what’s afoot is one triggered first and foremost by oversupply. 

As one noted in a recent Forbes column, the oversupply situation – not just for oil but a whole host of commodities – merits a deeper examination. The week before we saw oil benchmarks plummet after the so-called ‘Black Monday’ (August 24) only for it recover by Friday and end higher on a week-over-week basis compared to the previous week’s close (see graph above, click to enlarge)

This was followed on Monday, August 31 by some hefty gains of over 8% for both Brent and WTI. Yet at the time of writing this blog post some 48 hours later, Brent had shed over 10% and the WTI over 7% on Tuesday but again gained 1.72% and 1.39% respectively on Wednesday.

The reasons for driving prices down were about as fickle as they were for driving them up and subsequently pulling them down again, and so it goes. When the US Energy Information Administration (EIA) reported on Monday that the country’s oil production peaked at just above 9.6 million barrels per day (bpd) in April, before falling by more than 300,000 bpd over the following two months; those in favour of short-calling saw a window to really go for it.

They also drew in some vague OPEC comment (about wanting to support the price in tandem with other producers), knowing full well that the phoney rally would correct. The very next day, as the official purchasing managers’ index for Chinese manufacturing activity fell to 49.7 in August, from the previous month’s reading of 50, some serious profit-taking began.

As a figure below 50 signals a contraction, while a level above that indicates expansion, traders found the perfect pretext to drive the price lower. Calling the price higher based on back-dated US data on lower production in a heavily oversupplied market is about as valid as driving the price lower based on China’s manufacturing PMI data indicative of a minor contraction in activity. The Oilholic reckons it wasn’t about either but nervous markets and naked opportunism; bywords of an oversupplied market.

So at the risk of sounding like a broken record, this blogger again points out – oversupply to the tune of 1.1-1.3 million bpd has not altered. China’s import level has largely averaged 7 million bpd for much of the year so far, except May. 

Yours truly is still sticking to the line of an end of year Brent price of $60 per barrel with a gradual supply correction on the cards over the remaining months of 2015 with an upside risk. Chances of Iran imminently flooding the market are about as likely as US shale oil witnessing a dramatic decline to an extent some in OPEC continue to dream off.

But to get an outside perspective, analysts at HSBC also agree it may take some time for the market to rebalance fully. “The current price levels look completely unsustainable to us and a combination of OPEC economics and marginal costs of production point to longer-term prices being significantly higher,” they wrote in a note to clients.

The bank is now assuming a Brent average of $55.4 per barrel in 2015, rising to $60 in 2016 and $70-80 for 2017/18. Barclays and Deutsche Bank analysts also have broadly similar forecasts, as does Moody’s for its ratings purposes.

The ratings agency sees a target price of $75 achieved by the turn of the decade, but for yours truly that moment is bound to arrive sooner. In the meantime, make daily calls based on the newsflow in this barmy market. That’s all for the moment folks! Keep reading, keep it crude!

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© Gaurav Sharma 2015. Graph: Oil benchmark Friday closes, Jan 2 to Aug 28, 2015 © Gaurav Sharma, August 2015.

Saturday, August 15, 2015

Resisting $40/bbl, Russia & some ‘crude’ ratings

Following two successive week-on-week declines of 6% or over, last Friday’s close brought some respite for Brent oil futures, although the WTI front month contract continued to extend losses. In fact, the US benchmark has been ending each Friday since June 12 at a lower level compared to the week before (see graph, click to enlarge).
 
Will a $40-floor breach happen? Yes. Will oil stay there? No. That’s because market fundamentals haven’t materially altered. Oversupply and lacklustre demand levels are broadly where they were in June. We still have around 1.1 to 1.3 million barrels per day (bpd) of extra oil in the market; a range that’s held for much of 2015. Influences such as Iran’s possible addition to the global crude oil supply pool and China not buying as much have been known for some time.

The latest market commotion is sentiment driven, and it’s why the Oilholic noted in a recent Forbes column that 2016-17 futures appear to be undervalued. People seem to be making calls on where we might be tomorrow based on the kerfuffle we are seeing today!

Each set of dire data from China, inventory report from the Energy Information Administration (EIA), or a gentle nudge from some country or the other welcoming Iran back to the market (as Switzerland did last week) has a reactive tug at benchmarks. The Oilholic still believes Brent will gradually creep up to $60-plus come the end of the year, with supply corrections coming in to the equation over the remainder of this year.

Away from pricing, there is one piece of very interesting backdated data. According to the EIA, Russia’s oil and gas sector weathered both the sanctions as well as the crude price decline rather well.

For 2014, Russia was the world's largest producer of crude oil, including lease condensate, and the second-largest producer of dry natural gas after the US. Russia exported more than 4.7 million bpd of crude oil and lease condensate in 2014, the EIA concluded based on customs data. Most of the exports, or 98% if you prefer percentages, went to Asian and European importers.

Where Russian production level would be at the end of 2015 remains the biggest market riddle. Anecdotal and empirical evidence points to conducive internal taxation keeping the industry going. However, as takings from oil and gas production and exports, account for more than half of Russia's federal budget revenue – it is costing the Kremlin.

Finally, two ratings notes from Fitch over the past fortnight are worth mentioning. The agency has revised its outlook on BP's long-term Issuer Default Rating (IDR) to ‘Positive’ from ‘Negative’ and affirmed the IDR at 'A'.

The outlook revision follows BP's announcement that it has reached an agreement in principle to settle federal, state and local Deepwater Horizon claims for $18.7bn, payable over 18 years. “We believe the deal has significantly reduced the uncertainty around BP's overall payments arising from the accident and hence has considerably strengthened the company's credit profile,” Fitch said.

The agency added there was a real possibility for an upgrade to 'A+' in the next 12 to 18 months, depending on how things pan out and BP's upstream business profile does not show any significant signs of weakening, such as falling reserves or production.

Elsewhere, and unsurprisingly, Fitch downgraded the beleaguered Afren to ‘D’ following the management's announcement on July 31 that it had taken steps to put the company into administration. The company's senior secured rating has been affirmed at 'C', and the Recovery Rating (RR) revised to 'RR5' from 'RR6'.

As discussions with creditors aimed at recapitalising the company failed, the appointment of administrators was made with the consent of the company's secured creditors who saw it as an “important step in preserving value of Afren's subsidiaries”. It is probably the only “value” left after a sorry tale of largely self-inflicted woes. That’s all for the moment folks, keep reading, keep it ‘crude’!

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© Gaurav Sharma 2015. Graph: Oil benchmark Friday closes, Jan 2 to Aug 14, 2015 © Gaurav Sharma, August 2015.

Sunday, August 09, 2015

Jargon free volume on upstream fiscal design

Takings from upstream oil and gas projects, whether they are small scale or big ticket ones, ultimately determine their profitability – the stuff that shareholders, venture sponsors and governments alike have a keen interest in.

It is why oil and gas companies, both state or privately held, deploy an army of petroleum economists to offer conjecture or calculated projections on what the final fiscal share of such ventures might be.

In this complex arena, both budding petroleum economists and established ones could do with all the help they can get. Industry veterans Ken Kasriel and David Wood’s book Upstream Petroleum: Fiscal and Valuation Modeling in Excel (published by Wiley Finance) goes a long way towards doing just that, and quite comprehensively too.

In a volume of 370 pages, with eight detailed chapters split into sequential sub-sections, the authors offer one of the most detailed subjective discussions and guidance on fiscal modeling that is available on the wider market at the moment in the Oilholic's opinion.

The treatment of fiscal systems, understanding and ultimately tackling the complexities involved is solid, predicated on their own views and experience of understanding the tangible value of upstream projects before, during and when they ultimately come onstream, and what the takings would be.

Kasriel and Wood have also included five appendices and a CD-ROM (in the hardcover version) to take the educational experience further, and accompanying the main text of the title are over 400 pages of supplementary PDF files and some 120-plus Excel files, with an introduction to risk modeling.

What is particularly impressive is the authors’ painstaking effort in cutting through industry jargon, putting across their pointers in plain English for both entry-level professionals and experienced practitioners. Furthermore, the sequential format of the book makes it real easy for the latter lot to jump in to a section for quick reference or for a subject specific refresher. 

Generic treatment of taxation, royalties, bonuses, depreciation, profit sharing mechanics, incentives, ringfencing, and much more, including decommissioning finance, are all there and should withstand the passage of time as both authors have called their combined 48 years of experience in the industry into play, to conjure up a reasonably timeless discussion on various issues. 

Above everything else, Kasriel and Wood’s conversational style makes this book a very purposeful, handy guide on a subject that is vast. The Oilholic is happy to recommend it to fellow analysts, (aspiring, new and established) petroleum economists, policymakers, industry professionals, corporate sponsors and oil and gas project finance executives.

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© Gaurav Sharma 2015. © Photo: Front Cover – Upstream Petroleum: Fiscal and Valuation Modeling in  Excel © Wiley Publishers, March, 2015.

Monday, July 20, 2015

Importance of Khazzan-Makarem gas field for BP

When the Oilholic paid a visit to Oman couple of years ago, natural gas was not atop the list of ‘crude’ industry intelligence gathering activities, one must admit. The Sultanate perhaps has the richest quality of all Middle Eastern crude oil varieties but there’s not a lot of it around, nor is Oman's reserves position anywhere near as strong as that of its neighbours.

Nonetheless, oil matters took up much of this blogger’s time and effort, including an excursion to the Musandam Peninsula, where Oman is in the process of having a decent crack at its first offshore exploration. The crucial subject of Omani natural gas largely slipped under the radar there and then, and largely up until now. 

That’s until this blogger recently met David Eyton, Group Head of Technology at BP, for a fascinating Forbes interview (click here) on how the oil major is using digital tools such as 4D seismic to reshape the way it operates both upstream and downstream, and the subject of Oman came up.

The country's Khazzan-Makarem gas field is in fact among the many places benefiting from BP’s research and development spend of around two-thirds of a billion dollars per annum towards digital enablement of surveying, and more. What’s at stake for BP, and for Oman, is Khazzan’s proven reserve base of 100 trillion cubic feet. Unlike Shell, its FTSE 100 peer, BP isn’t digging for oil in the Sultanate, making the gas field – which it discovered in 2000 – a signature play.

At its core is Block 61, operated by BP Oman and Oman Oil Company Exploration and Production in a 60:40 joint venture partnership. Eyton says some of BP’s patented digital tools, including 4D seismic, are being deployed to full strength with a drilling schedule of approximately 300 wells over a 15 year period to achieve a plateau production rate of 1.2 billion cubic feet of gas per day.

“Khazzan has massive potential. It’s not shale in the strictest sense, but pretty tight gas and mighty difficult to crack owing to the low porosity of the reservoir rock,” Eyton said.

Invariably, BP has brought the full works into play to realise Block 61’s potential, drilling horizontal wells and using hydraulic fracturing technologies. "Advanced seismic imaging has played a huge part in understanding where the best bits of the reservoir are, and how to unlock them. Ultimately, that’s enabling development to proceed at a far better pace."

Construction work on Khazzan has commenced and first gas is expected in late 2017. Implications of Block 61 yielding meaningful volumes, as expected, cannot be understated. For Oman, the projected 1.2 bcf in daily production volume would be equivalent to an increment of over 30% of its total daily gas supply.

Concurrently, BP would look back in satisfaction at a Middle Eastern foray on business terms few oil and gas markets, bar Oman, would offer in an age of resource nationalism. As for the technology being deployed, it is already a winner, according to Eyton. That’s all for the moment folks! Keep reading, keep it ‘crude’!

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© Gaurav Sharma 2015. Photo: David Eyton, Group Head of Technology at BP © Graham Trott / BP