BG Group’s been ‘Shell-ed’

In case you have been away from this ‘crude' planet and haven’t heard, oil major Royal Dutch Shell has successfully bid for its smaller FTSE 100 rival BG Group in a cash and shares deal valuing the latter at around £47 billion (US$70 billion).

While it’s early days into the current calendar year, the deal, subject to approval by shareholders, could be one of the biggest of 2015 producing a company with a combined value of over £200 billion.

For the Anglo-Dutch oil major, BG Group's acquisition would also add 25% to its proven oil and gas reserves and 20% to production capacity, along with improved access to Australian and Brazilian prospects. BG Group shareholders will own around 19% of the combined group following the deal.

BG Group's new chief executive Helge Lund, who only took up the post last month, will remain with the company while the deal is being worked on. However, he is expected to leave once it is completed walking away with what many in the City reckon to be a £25 million golden goodbye. The Oilholic thinks that’s not too bad a deal for what would come to little over three months of service.

BG Group shareholders, who’ve had to contend with a lacklustre share price for the last 12 months given the company’s poor performance, can also expect a decent windfall should they choose to sell. The bid values BG at around 1,350p per share; a near 50% premium to its closing price of 910.4p on Tuesday. If they decide to hold on to their shares, they’d be likely to receive an improved "Shell of a dividend" from a company that has never failed to pay one since 1945.

Shell chief executive Ben van Beurden said, "Bold, strategic moves shape our industry. BG and Shell are a great fit. This transaction fits with our strategy and our read on the industry landscape around us."

The market gave the news a firm thumbs up. Investec analyst Neill Morton said BG’s long-suffering shareholders have finally received a compelling, NAV-based offer while Shell’s bid was arguably “20 years” in the making.

“We agree that BG’s asset base is better suited to a larger company, but the economics require something approaching Shell’s $90/bl assumption. Consequently, we do not expect a rival bid and are wary of this catalysing a flurry of copycat deals. But we are also mindful that investment bankers can be very persuasive! We suspect Shell aims to re-balance dividends versus buybacks over the long-term. This could imply lower dividend growth,” he added.

As for the ratings agencies, given that the deal completion is scheduled for H1 2016, and quite possibly earlier given limited regulatory hurdles, Fitch Ratings placed Shell's ratings on Rating Watch Negative (RWN) and BG Group's ratings on Rating Watch Positive (RWP).

The agency aims to resolve the Rating Watches on both companies pending the successful completion of the potential transaction and “once there is greater clarity with regard to Shell's post-acquisition strategy and potential synergy effects.” We’re all waiting to hear that, although of course, as Fitch notes – Shell's leverage will increase.

“Our current forecasts suggest that the company's funds from operations (FFO) adjusted net leverage will increase from 1.5x at end-2014 to around 2x in 2015-2017 based on conservative assumptions around the announced $30 billion divestment programme and execution of the announced share buybacks from 2017.”

Moody’s has also affirmed its Aa1 rating for Shell, but quite like its peers changed the company’s outlook to negative in the interim period pending the completion of the takeover. Meanwhile, some City commentators have speculated that Shell's move might trigger a wave of M&A activity in the oil and gas sector.

However, the Oilholic remains sceptical about such a rise in M&A. In fact, one is rather relieved that the Shell and BG Group saga would cool nonsensical chatter about a possible BP and Shell merger (oh well...there's always ExxonMobil).

They’d be the odd buyout or two of smaller AiM-quoted independents, but bulk of the activity is likely to remain limited to asset and acreage purchases. Of course, consolidation within the sector remains a possibility, but we are too early into a cyclical downturn in the oil market for there to be aggressive overtures or panic buying. However, 2016 could be a different matter if, as expected, the oil price stays low.

Moving away from the Shell and BG show, here is one’s take via a Forbes column on how oil markets should price in the Iran factor, following the conclusion of pre-Easter nuclear talks between the Iranians and five permanent members of UN Security Council plus Germany.

Additionally, here’s another one of the Oilholic’s Forbes posts on why a decline in US shale activity is not clear cut. As it transpires, many shale producers are just as adept at coping with a lower oil price as any in the conventional industry. That’s all for the moment folks! Keep reading, keep it ‘crude’!

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© Gaurav Sharma 2015. Photo: Vintage Shell petrol pump, San Francisco, USA © Gaurav Sharma

Oil storage, Chinese imports & Afren’s CEO

When the oil price is rocky, it seems storage in anticipation of better days is all the rage. Afterall, it does take two to play contango, as the Oilholic recently opined in a Forbes column. But leaving those wanting to play the markets by the side for a moment, wider industry attention is indeed turning to storage like never before.

We are told the US hub of Cushing, Oklahoma has never had it so good were we to rely on Genscape’s solid research on what’s afoot. In trying times, the industry turns to the most economical onshore storage option on the table. For some, actually make that many, Cushing is such a port of call.

As of February-end, Genscape says 63% of Cushing’s storage capacity has already been utilised. Capacity has never exceeded 80%, since Genscape began monitoring storage at Cushing in 2009. So were heading for interesting times indeed!

Meanwhile, the country now firmly established as the world’s top importer of crude oil – i.e. China – might well be forced to import less owing to shortage of storage capacity! Well established contacts in Shanghai have indicated to this blogger that in an era of low prices, Chinese policymakers were strategically stocking up on crude oil.

With Chinese economic data being less than impressive in recent months, it probably explains where a good portion of the 7.1 million barrels per day (bpd) imported by the country in January and February went. However, now that available storage is nearly full, anecdotal evidence suggests Chinese oil imports are going to drop off.

Import volumes for April are not likely to be nearly as strong. As for the rest of the year, the Oilholic expects Chinese imports to stay flat. Furthermore, Barclays analysts believe putting faith in China’s economic growth to support oil prices would be “premature” at best, with the country undergoing structural changes.

On a related note, lower oil prices will also slow the revenue growth of Chinese oilfield services (OFS) companies as their upstream counterparts continue to cut capex. Putting it bluntly, Chenyi Lu, Senior Analyst at Moody’s noted: "In addition to the impact on revenues, Chinese OFS companies will also see their margins weaken over the next two years as their exploration and production customers negotiate lower rates."

Finally, before yours truly takes your leave, it seems the beleaguered London-listed independent upstart Afren has finally named a new CEO following its boardroom debacle. Industry veteran Alan Linn will take-up his post as soon as the company’s “imminent” $300 million bailout is in place. We wish him all the luck, given his task at hand. That’s all for the moment folks! Keep reading, keep it ‘crude’!

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© Gaurav Sharma 2015. Photo: Oil pipeline, Fairfax, Virginia, USA © O. Louis Mazzatenta / National Geographic

Oil prices, OPEC shenanigans & the North Sea

It has been a crude fortnight of ups and downs for oil futures benchmarks. Essentially, supply-side fundamentals have not materially altered. There’s still around 1.3 million barrels per day (bpd) of crude oil hitting the markets in excess of what’s required.

Barrels put in storage are at an all time high, thanks either to those forced to store or those playing contango. US inventories also remain at a record high levels. 

However, the biggest story in the oil market, as well as the wider commodities market, is the strength of the US dollar. All things being equal, the dollar’s strength is currently keeping both Brent and WTI front month futures contracts at cyclical lows. The past five trading days saw quite a few spikes and dives but Friday’s close came in broadly near to the previous week’s close (see graph on the left, click to enlarge).

In the Oilholic’s opinion, a sustained period of oil prices below $60 is not ideal for unconventional exploration. Nonetheless, not all, but a sufficiently large plethora of producers just continue to grin and bear it. While that keeps happening, and the dollar remains strong, oil prices will not find support. We could very well be in the $40-60 range until June at the very least. Unless excess supply falls from 1.3 million bpd to around 750,000 bpd, it is hard to see how the oil price will receive support from supply constriction. 

Additionally, Fitch Ratings reckons should Brent continue to lurk around $55, credit ratings of European, Middle Eastern and African oil companies would take a hit. European companies that went into the slump with stretched credit profiles remain particularly vulnerable.

In a note to clients, Fitch said its downgrade of Total to 'AA-' in February was in part due to weaker current prices, and the weaker environment played a major part in the downgrade and subsequent default of Afren.

"Our investigation into the effect on Western European oil companies' credit profiles with Brent at $55 in 2015 shows that ENI (A+/Negative) and BG Group (A-/Negative) were among those most affected. Both outlooks reflect operational concerns, ENI because of weakness in its downstream and gas and power businesses, BG Group due to historical production delays. Weaker oil prices exacerbate these problems," the agency added.

Of course, Fitch recognises the cyclical nature of oil prices, so the readers need not expect wholesale downgrades in response to a price drop. Additionally, Afren remains an exception rather than the norm, as discussed several times over on this blog.

Moving on, the Oilholic has encountered empirical and anecdotal evidence of private equity money at the ready to take advantage of the oil price slump for scooping up US shale prospects eyeing better times in the future. For one’s Forbes report on the subject click here. The Oilholic has also examined the state of affairs in Mexico in another detailed Forbes report published here.

Elsewhere, a statement earlier this week by a Kuwaiti official claiming that there is no appetite for an OPEC meeting before the scheduled date of June 5, pretty much ends all hopes of the likes of Nigeria and Venezuela in calling an emergency meeting. The official also said OPEC had “no choice” but to continue producing at its current levels or risk losing market share.

In any case, the Oilholic believes chatter put out by Nigeria and Venezuela calling for an OPEC meeting in the interest of self-preservation was a non-starter. Given that we’re little over two months away from the next meeting and the fact that it takes 4-6 weeks to get everyone to agree to a meeting date, current soundbites from the ‘cut production’ brigade don’t make sense.

Meanwhile, the UK Treasury finally acknowledged that taxation of North Sea oil and gas exploration needed a radical overhaul. In his final budget, before the Brits see a General Election on May 7, Chancellor George Osborne cut the country’s Petroleum Revenue Tax from its current level of 50% to 35% largely aimed at supporting investment in maturing offshore prospects.

Furthermore, the country’s supplementary rate of taxation, lowered from 32% to 30% in December, was cut further down to 20% and its collection at a lower rate backdated to January. Altogether, the UK’s total tax levy would fall from 60% to 50%.

Osborne’s move was widely welcomed by the industry. Some are fretting that he’s left it too late. Yet others reckon a case of better late than never could go a long way with the North Sea’s glory days well behind it. That’s all for the moment folks! Keep reading, keep it ‘crude’!

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© Gaurav Sharma 2015. Graph: Tracking Friday oil prices close, year to date 2015 © Gaurav Sharma, March 20, 2015.

Viewing US oil output through Drillinginfo’s lens

Perceptions about massive a decline in US oil production currently being put forward with such fervour and the ground reality of an actual one taking place are miles apart; or should we say barrels apart. 

Assuming that a decline in production stateside would start eroding the oil supply glut thereby lending slow but sure support to the oil price is fine. But declarations on the airwaves by some commentators that a North American decline is already here, imminent or not that far off, sound too simplistic at best and daft at worst.

The Oilholic agrees that Baker Hughes rig count, which this blog and countless global commentators rely upon as a harbinger of activity in the sector, has shown a continual decline in operational rigs over recent weeks and months. However, that does not paint a complete picture.

Empirical and anecdotal data from Canada demonstrates that Western Canadians are aiming to do more with less. According to research conducted by the Canadian Association of Petroleum Producers (CAPP), fewer wells would be dug this year but production will actually rise on an annualised basis over 2015. That’s despite the fact that the Western Canadian Select fell to US$31 per barrel at one point.

There’s a similar story to be told in the US of A, and digital disruptors at Drillinginfo are doing a mighty fine job of narrating it. The Austin, Texas headquartered energy data analytics and SaaS-based decision support technology provider opines that much of the current conversation obsessively intertwines the oil price dip with a decline in activity, bypassing efficiencies of scale and operations achieved by US shale explorers.

“Our conjecture is that an evident investment decline does not imply that production is nose-diving in tandem. Quite the contrary, our research suggests exploration and production firms are 25% more efficient than they were three years ago,” says Tom Morgan, Analyst and Corporate Counsel at Drillinginfo.

It’s not that Drillinginfo is not recording dip in rig counts and new drilling projects coming onstream via its own DI Index. Towards the end of February, its US rig count stood at 1433, while new US oil production dipped 9% on the month before to 525 million barrels per day (bpd). However, if what’s quoted here sounds better than what you’ve heard elsewhere then it most probably is for one simple reason.

“What we put forward is in real-time. Two years ago, we started handing out GPS trackers to operators to latch on to their rigs. It was not easy convincing an old fashioned industry to immediately warm up to what we were attempting to do. It was a long drawn out process but we converted many people around to our viewpoint.

“At present, over 80% of rigs in continental US are reported on daily via Drillinginfo installed GPS units. In return, the participants get free access to our collated data. At this moment in time, not only can I point out each of these rigs via a heat signature (see image from January above left, click to enlarge), but also pinpoint the coordinates for you to locate one, drive there and verify yourself. I’d say our data is 99% accurate based on back testing and reconciling trends with our archives,” Morgan adds.

Drillinginfo also examines the actual spud of a well that's been drilled but not yet completed, as well as permit applications. “The thought process in case of the latter is that if you have applied for a permit to drill, then you are more than likely [if not a 100%] sure of going ahead with it.”

Drillinginfo saw a 24% decline in US permit application between January and February. This shows that investment is slowing down, yet at the same time operational wells are generally on song. With the end of first quarter of this year in sight, the US is still the world’s leading producer in barrels of oil equivalent terms.

Oil production continues to rise, albeit not in incremental volumes noted over the first and second quarters of last year prior to the slump. US producers, or shall we say those producers who can, are strategically lowering operations in less bankable or logistically less connected shale plays, while perking up production elsewhere.

For instance, while the collated production level at Bakken shale plays in North Dakota is declining, production at Eagle Ford shale in Texas has risen to 159,000 bpd; a good 26,000 bpd above levels seen towards the end of last year.  In terms of the type of wells, Drillinginfo sees older vertical wells bear the brunt of the slump, while production at onstream horizontal wells is either holding firm or actually rising a notch or two.

“No one is pretending that market volatility and the oil price slump isn’t worrying. What we are encountering is that shale players are trying to achieve profitability at a price level we could not imagine ten, five or even three years ago because technology has advanced and efficiencies have improved like never before,” Morgan adds.

While pretty reliable, feed-through of information via the Baker Hughes rig count is not real-time but looking backwards based on a telephone and electronic submission format. By that argument, the Oilholic finds what Drillinginfo has to say to be an eye-opener in the current climate, particularly in an American context. 

However, company man Morgan, who has known Drillinginfo's co-founder and CEO Allen Gilmer since both their freshmen years at Rice University back in the 1980s, has a more polished description.

“Today we talk of heat map of rigs, real-time data, rig movement monitoring, type and location of rigs going offline, and much more. I’d say we’re bringing agility via a digital medium to participants in a very traditional business.”

That agility and sense of perspective is something the industry does indeed crave, especially in the current climate. The Oilholic would say what Genscape is bringing to storage monitoring; Drillinginfo is bringing to upstream data analytics. That’s all for the moment folks! Keep reading, keep it ‘crude’!

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© Gaurav Sharma 2015. Graphic: Map of new US wells drilled in January 2015, and those drilled within the last six months © Drillinginfo, 2015

Summing up the ‘crude’ mood in Houston

The Oilholic finds the mood in Houston to be rather dark on his latest visit, and the weather here seems to be reflecting it. Oil price remains shaky, local refineries are battling strikes and shutdowns.

Meanwhile, as expected the Obama Administration has vetoed the Keystone XL pipeline project as the farcically prolonged tussle about an extension that’s meant to bring Canadian crude to Texan refineries continues.

Unsurprisingly, Texas is mirroring the globally evident trend of oil and gas sector job cuts, and costs of redundancies are more visible in an oil hub like Houston.

However, local commentators say the city (and by extension the state) has seen slumps in the global oil markets before, will see it again and remains capable enough to weather this latest one.

Dr Vincent Kaminski, an industry veteran and prominent academic at Rice University, says there’s no panic in the ranks even if the euphoria of a $100 per barrel price has long gone. “The word ‘caution’ is being branded about. No one can predict how long this period of lower oil prices is going to last. There is consensus that the price will bounce back, though not to the highs of 2013-14 unless there is a geopolitical development of a magnitude that would neutralise the impact of oversupply. Right now, there isn’t an obvious one.”

Kaminski feels what’s critical here is the management of this period of depressed prices, especially on the human capital front. Anecdotal evidence and published data suggests companies that are firing are not hiring with the same pace for the moment.

Deborah Byers, Managing Partner of global advisory firm EY’s Houston Office, says managing human resources is critical in the current climate. “My fear is that not everybody will get it right. Letting people go in a tough climate is a reactionary move; re-hiring talent when the market bounces back isn’t. A lot people in Houston have reacted very quickly. I agree that the supply glut has infused a bit of disciple in the sector, but it’s a nuanced situation to 2008-09.

“What we are seeing is a profound structural change leading to a transition towards a different type of market. In wake of the global financial crisis, we had a lack of demand scenario; what’s afoot now is a story of oversupply. That said, over the long-term the current situation would turn out to be a good story.”

Louis J. Davis, Chair of international law firm Baker & McKenzie’s North America Oil & Gas Practice, says the speed of the oil price decline caught many in Houston by surprise. “Some clients foresaw it, but not with the speed with which the decline hit home. Companies in the exploration and production (E&P) business are going to hold back on activity, lay down rigs and wait for a level of stability in the global markets. That’s unless they have existing well commitments.

“Nobody wants to drill uneconomic wells; including those who are hedged. It’s about keeping reserves up; and hedges are going to periodically roll-off within a 3 to 12 month window. By then, if a broader recovery, or at least a level of stability within a price bracket that's considered viable, is not achieved you'll find a lot of worried people.”

Furthermore, as Davis points out, even for those who are neatly hedged, their borrowing base is going to drop because they are not going to replenish their reserves by drilling additional wells. The Baker & McKenzie veteran says quite a few of his clients are in fine fettle but cautious.

“Many see opportunities when the market goes through a cyclical correction, and that hasn’t changed. There is a lot of money out there to buy promising assets at better prices. That said, interaction with people I’ve known for 40 years, as well as anecdotal evidence from a recent NAPE expo suggests the M&A deal flow is very slow right now. 

“Some deals that have been signed up are not closing, and no one is in a rush to close. Some are even taking the pain of letting their holding deposit slip. Yet, I’d say the present situation is troubling, but not an unseen one for Houston. We've been here before.”

Kaminski, Byers and Davis are united in their opinion that Houston’s economy is way more diversified than it was in the 1980s. As Kaminski points out – the city’s thriving Medical Center, adjacent to Rice University, employs more people than back office and ancillary staff at oil and gas companies.

Services, higher education, real estate and technology sectors are other major contributors to metropolitan and regional growth. There is evidence that the real estate market is slowing down in wake of oil and gas sector downturn. However, this is also not uniform across the greater Houston area; there are discrepancies from area to area.

Finally, Byers says corporate leaders within the sector always pause and reflect at such junctures. “For me personally, this is my fourth cyclical downturn – 1986, 1999, 2008-09 and now 2014-15. Couple of CEOs I’ve known and worked with for decades, say we’ve seen this before and we know what levers to pull. The question is how long will the duration of the downturn be and how long do we need to pull those levers before we switch back to an offensive mode.”

That’s a billion dollar question indeed; one that's guaranteed to be asked several times over the course of this year. That’s all for from Houston folks. Keep reading, keep it ‘crude’!

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© Gaurav Sharma 2015. Photos: Glimpses of downtown Houston, Texas, USA © Gaurav Sharma, 2015