Showing posts with label shale. Show all posts
Showing posts with label shale. Show all posts

Sunday, February 18, 2024

Rising shale output & oil's recovery to November levels

At the start of the year there were some doubts whether US shale oil production would remain high, having broken records in 2023 and propelled the States to the top of the global oil production leader-board

But a recent update from the Energy Information Administration (EIA) has gone some way in dispelling those doubts. 

The statistics arm of the US Department of Energy projects that production will likely  go up in March. Key basins are expected to produce around 20,000 more barrels per day (bpd) next month. This implies a total of 9.7 million bpd in shale production - a volume that hasn't been recorded since December last year. 

Conventionally, you'd think an upbeat US production forecast would knock a few dollars off crude prices. However, the market is more or less holding firm, as the Oilholic noted in an earlier blog post. After the profit-taking of last few weeks cooled, the last couple of sessions have seen oil futures return to levels not seen since November. That'd be $83+ per barrel prices for the Brent front-month contract and $79+ per barrel for the WTI.

A combination of OPEC+ cuts, Moscow's recent (and well documented) difficulties in shifting its crude owing to Western sanctions and heightened geopolitical tensions in the Middle East are keeping oil prices at elevated levels. 

However, the Oilholic reckons the price will face resistance at $85 and the upcoming week should be interesting. (And the EIA's next update - in this data series - is on March 18, and next weekly US inventory report is out on February 22). 

Elsewhere, yours truly participated in a panel discussion on TRT World's Round-table program to discuss Italy's overtures to Africa for its energy security needs whilst addressing the thorny issue (or shall we say the political hot potato) of migration. 

One guesses, that in reaching out to African heads of state ahead of the Gas Exporting Countries Forum (GECF)'s next high-level summit in Algeria in March, Italy's Prime Minister Giorgia Meloni has made a strategic and pragmatic move. (The full broadcast is available here)

And finally, remember Uniper? And it's bailout by the German government in 2022 after its options for Russian gas imports ran out? Well its back with a bang, and ready to repay (some of) the bailout money back in phases. That's just as Berlin is seemingly contemplating a share sale to recoup (some of) the money. Here's a full Forbes report. Well that's all for now folks. More soon. Keep reading, keep it here, keep it 'crude'! 

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© Gaurav Sharma 2024. Photo: Oil well in Oman © Shell. 

Monday, June 10, 2019

That US oil production chart by the EIA

Market chatter over US oil production appears to be all the rage these days, with many forecasters predicting 2019 to be another record year for the Americans. Some are even predicting US production to be as high as 13.4 million barrels per day (bpd) in 2019. 

At the moment, its lurking around 12.3 million bpd according to the EIA. However, the chart below sums it up, and kinda explains why some commentators are so upbeat, given the trajectory of official data and related projections. Please click to enlarge chart. That's all for the moment folks, as the Oilholic is in Oslo, Norway for a conference. More from here shortly! Keep reading, keep it 'crude'!


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© Gaurav Sharma 2019. Photo: US oil production and projection © US EIA, May 2019

Friday, August 10, 2018

Gazing at DJ Basin’s ‘Shale Gale’ with Highlands Natural Resources

Last month, the Oilholic headed stateside to get a 'crude' glimpse of drilling activity in the Denver Julesburg or 'DJ' Basin in Colorado; this blogger's first visit to the region. The basin has been a key hydrocarbon producing region of the US since 1901. Over a century later, it's still going strong courtesy of the state of Colorado's very own 'Shale Gale.' 

Colorado's legislative climate might be a bit onerous compared to Texas, but the basin still remains a relatively benign place for exploration and production, and yes the oil majors are all there poking around the place.

Also, what won't surprise regular readers of this blog one bit is that regional activity is being bolstered by - you guessed it - the independent upstarts, or new-age shale wildcatters as the Oilholic prefers to call them. 

In this august group is London-listed Highlands Natural Resources (HNR), the brainchild of entrepreneur and local oilman Robert Price, and his close-knit group of geologists, engineers, financiers and consultants. The company's simple but effective motto – in Price's own words – is to deliver projects "safely, on time and on budget."

The company has farmed out acreage from ConocoPhillips out in East Denver, is not only trialling Halliburton's cost and process optimising Integrated Asset Management (IAM) suite of techniques to the fullest, but also has a stake in its operations from the global oilfield services company itself; a rather unique scenario. 

HNR's site in the Lowry Bombing Range, East Denver (see above left), visited by this blogger in Price's company, sees just the sort of savvy operations predicated on big data that we often hear about in the popular press. For example, in an area where players are attempting to drill 16 or 24 wells in the same pad, Domingo Mata, HNR's Vice President of Engineering, says his company has opted for 8 wells, as studies have convinced the management that fewer wells will provide a better yield.

"We also keep an eye on the minutiae of the drilling process via a plethora of sensors. That's how we gather data and learn lessons from the drilling process in the case of each well, and bring about a sequential reduction in drilling times by improving upon past processes based on what the data revealed about the last round of works," Mata adds.

In some cases, that drilling time has come down to 10-14 days; and we're talking depths in the range of 17,000 to 19,000 feet. Price says optimised operations are the bedrock of his company and together with his chief geologist Paul Mendell, HNR is "astute and prudent" in managing its exposure to what has been, is, and will always remain, a high risk, high reward business. 

On the East Denver site the Oilholic had a walkabout, HNR now has a 7.5% carried interest in first 8 wells to produce at the project with additional upside potential to own 7.5% interest in up to 24 wells at no extra cost. The arrangement is boosted by a strong working relationship with majority holder True Oil. 

The site carries a potential yield of 5,000 barrels per day (bpd) of one of the sweetest and best crudes (see right) this blogger has seen since a visit to Oman back in 2013. The product is currently being brought to market via tanker trucks, but will soon be hooked up to ConocoPhillips' pipeline infrastructure. 

And HNR has received £2.9 million of income during four months up to 31 March 2018 from just two wells – Powell and Wildhorse – which sit in the top 3% of all horizontal DJ Basin (Niobrara) wells in Colorado. 

Not wanting to sit on its existing plays, the company is now eyeing West Denver prospects. HNR owns a direct 100% working interest in leases covering 2,721 acres in the area, where Price reckons his team, partners, contractors and affiliates can collaboratively drill at least 48 wells.

What's more the surface area is largely free of urban development and consolidated into closely grouped parcels, and may allow HNR to move through Colorado's permitting and development processes quicker relative other statewide plays.  

Price and Mendell have also made it their mission to diversify HNR. The company is looking to market and monetise its DT Ultravert technology for enhanced oil recovery, which it claims will help the wider industry achieve at least a 15% increase in production. 

It has been proven to prevent 'well bashing' in horizontal and vertical wells. If the monetisation of DT Ultravert takes off, it could be a game-changer for the company, which is incidentally also in the business of Helium and Nitrogen plays.

All things considered, could Team HNR be described as 'Shale Gale' mavericks? "I think prudent, efficient, low-risk operators would be what I'd humbly describe us as," says Price. Well there you have it folks! It was a pleasure exchanging views with Team HNR (above) and seeing what they are up to.

Depending on whom you rely on, ranging from the US Energy Information Administration's projections to estimates by the likes of Anadarko Petroleum, the DJ basin could hold up to 4.5-5 billion barrels of oil equivalent for viable extraction (including natural gas liquids). 

That suggests there's plenty going around for the likes of HNR to continue tapping away at the reserves in their own cost optimised way. So here's to ingenuity and the spirit of private enterprise that has come to symbolise the shale revolution. That's all for the moment; keep reading, keep it ‘crude’!

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© Gaurav Sharma 2018. Photo I: Highlands Natural Resources' East Denver drilling site. Photo II: Glimpse of Denver light sweet crude produced by Highlands Natural Resources. Photo III: (Left to Right) Gaurav Sharma with Robert Price, CEO & Chairman, Highlands Natural Resources, and Domingo Mata, Vice President of Engineering, Highlands Natural Resources © Gaurav Sharma, 2018.

Friday, March 09, 2018

Frackers on the side of geopolitical angels?

IHS CERA Week 2018’s day two and three whizzed by with plenty of more talking points, some predictable, and well some not so predictable, with the oil price seesawing in the backdrop. 

Both benchmarks spent much of Monday and Tuesday on the up, and all of Wednesday and Thursday shedding those gains, with speaker after speaker suggesting US shale and the country's oil and gas exports were not a fad. 

Among them was US President Donald Trump's emissary – Energy Secretary Rick Perry – who emphatically declared on Wednesday that American producers were now allies of energy deficient nations craving energy security. 

Here’s the Oilholic’s report for Forbes with Perry’s...er...Trumped up soundbites. That said the US Energy Secretary is right – even the most pessimistic of shale decline rate forecasts suggest elevated oil and gas production volumes are here to say for at least another 10 years. 

"The U.S. has now become a net natural gas exporter. Our producers export liquefied natural gas (LNG) to 27 nations on five continents. In the coming years, you can expect more of the same," Perry reminded CERA Week delegates and you can expect more of the same. 

On a related note, here’s the Oilholic’s Forbes research into what incremental volumes of US LNG exports mean for the market, and the profound changes new players on the scene are bringing about. It has the thoughts of experts from Baker McKenzie, S&P Global Platts, KPMG, IHS Markit and ABB. 

Switching tack to some interesting soundbites over the last couple of days, Qatar's Oil Minister Mohammed Al-Sada said both oil producers and consumers were losing due to oil price volatility either side of the price slump in 2014. "Neither very high nor very low prices are good for global GDP. So OPEC had to intervene responsibly," he said of the ongoing OPEC and non-OPEC oil production cuts.

Bob Dudley, CEO of oil giant BP, admitted: "Our downstream business effectively funds the billions of dollars we pay in dividends."

Additionally, he noted that the UK oil & gas industry was going through "a renaissance; after remarkable, painful restructuring in the North Sea was behind it."

Dudley, also reiterated his stance from IPWeek a fortnight ago that his company and the rest of the energy industry is in a race to lower carbon emissions, not a race to lower emissions. ‏

Elsewhere, here's the Oilholic's Forbes interview with BP's Chief Scientist Dame Angela Strank on the crucial topic of gender diversity in the oil and gas business, and the vital need for the industry to continue to promote and emphasise the importance of STEM career pathways. 

And before one takes your leave, here's a glimpse of a Formula E car (above right) on display at the CERA Week tech floor. Pretty slick, bring on the electric car revolution! That's all for the moment from Houston folks! Keep reading, keep it 'crude'!

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© Gaurav Sharma 2018. Photo 1: US energy secretary Rick Perry at an IHS CERA Week 2018 press briefing. Photo 2: Formula E car on display at CERA Week's technology floor, Houston, Texas, USA. © Gaurav Sharma 2018.

Sunday, March 06, 2016

Aubrey McClendon (1959 – 2016): A flawed titan?

On Saturday, March 5, a riverfront in USA’s Oklahoma City saw well wishers, former employees, friends and family of controversial energy sector entrepreneur Aubrey McClendon, gather to pay their respects, following his death in a car crash on March 2; a day after being indicted on bid-rigging charges following an antitrust investigation by the US Department of Justice.

In keeping with his swashbuckling life, the end, when it came, was just as dramatic. While a police investigation into the crash is still ongoing, reports said the Chevy Tahoe McClendon was driving slammed straight into a cement wall, despite the driver having had multiple opportunities to avoid the collision. It was also revealed that he was not wearing his seat-belt.  

That was the final act of a glittering, albeit controversial oil and gas industry titan. As the shale bonanza took off stateside, McClendon was one of the poster boys of rising US natural gas production, taking Chesapeake Energy – a company he co-founded in 1989 at the young age of 29 – to the second spot on the country’s top gas producers’ roster by volume.

But in 2013, he was ousted from Chesapeake following damaging revelations that he had personal stakes in wells owned by the company. An accompanying corporate governance crisis tarnished his reputation further.

Yet, McClendon’s penchant for lavish spending never subsided. His investments in property, restaurants and businesses are littered across Oklahoma City. Famously, in 2008, he brought the National Basketball Association's Supersonics franchise to Oklahoma City from Seattle, renaming them Oklahoma City Thunder.

Following the Chesapeake debacle, McClendon marked a return to the industry by setting up a new company – American Energy Partners. Being the wildest of wildcatters, he made bets, not all of them sound, worth billions of dollars buying land with potential for oil and gas drilling.

However, all was not well with the US Justice Department set to haul him to the courts. He was alleged to have put in place a scheme between two “large oil and gas companies” to not bid against each other for leases in northwest Oklahoma from December 2007 to March 2012, to keep the price of leasing drilling rights artificially low, the Department of Justice said a day before his sudden death.

The American antitrust law – Sherman Act – which McClendon was accused of violating carries a maximum prison sentence of 10 years and a $1 million fine. 

None of this mattered to the hundreds who gathered on Saturday at Oklahoma City's Boathouse District to pay their respects to McClendon, with a formal public memorial service due on Monday at a local community church.

For them, the state in general and the city in particular, McClendon was instrumental in reviving the regional economy. As for the US shale industry, his impact in the history books – the good, the bad, the ugly, the unproven and the controversial. However, in his untimely passing, it is McClendon’s ingenuity that ought to be remembered by most.

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To email: gaurav.sharma@oilholicssynonymous.com

© Gaurav Sharma 2016. Photo: A shale drilling site © Chesapeake Energy.

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

Wednesday, April 08, 2015

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

Friday, March 20, 2015

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.

Thursday, March 06, 2014

Crude permutations of the Ukrainian stand-off

When the Russo-Georgian skirmish happened in 2008, European policymakers got a stark reminder of how reliant they were on Russian natural gas. Regardless of the geopolitics of that conflict, many leading voices in the European Union, especially in Germany, vowed to reduce their reliance on Russian gas.

The idea was to prevent one of the world's leading exporters of natural gas from using its resource as a bargaining tool should such an episode occur again. Now that it has, as the Ukrainian crisis brings Russia and West into yet another open confrontation, the Oilholic asks what happened to that vow. Not much given the scheme of things! What's worse, the Fukushima meltdown in Japan and a subsequent haphazard dismissal of the nuclear energy avenue by many European jurisdictions actually increased medium-term reliance on mostly Russian gas.

According to GlobalData, Russian gas exports to Europe grew to a record of 15.6 billion cubic feet per day last year. The US, which is not reliant on Russian natural resources, finds itself in a quandary as EU short-termism will almost certainly result in a toning down of a concerted response by the West against Russia in the shape of economic sanctions.

The human and socioeconomic cost of what's happening in Crimea and wider Ukraine is no laughing matter. However, President Vladimir Putin should be allowed a smirk or two at the idiocy and short-sightedness of the EU bigwigs – reliant on him for natural gas but warning him of repercussions! Therefore, sabre rattling by Brussels is bound to have negligible impact.

Meanwhile, Russia's Gazprom has said it will no longer offer Ukraine discounted gas prices because it is over US$1.5 billion in payment arrears which have been accumulating for over 12 months. Additionally, Rosneft could swoop for a Ukrainian refinery, according to some reports. While economic warfare has already begun, this blogger somehow does not see Russians and Ukrainians shooting at each other; Georgia was different.

Having visited both countries in the past, yours truly sees a deep familial and historic bond between the two nations; sadly that's also what makes the situation queasy. The markets are queasy too. Ukraine was hoping for a shale gas revolution and Crimea – currently in the Kremlin's grip – has its own shale bed. In November 2013, Chevron signed a $10 billion shale gas production sharing agreement with the Ukrainian government to develop the western Olesska field. Shell followed suit with a similar agreement.

Matthew Ingham, lead analyst covering North Sea and Western Europe Upstream at GlobalData, says shale gas production was inching closer. "Together with the UK and Poland, Ukraine could see production within the next three to four years."

However, what will happen from here is anyone's guess. A geopolitical bombshell has been dropped into the conundrum of exploratory and commercial risks.

Away from gas markets, the situation's impact on the wider crude oil market could work in many ways. First off, rather perversely, a mobilisation or an actual armed conflict is price positive for regional oil contracts, but not the wider market. A linear supply shortage dynamic applies here.

An economic tit-for-tat between Russia and the EU, accompanied by a conflict on its borders, would hurt wider economic confidence. So a prolonged escalation would be price negative for the Brent contract as economic activity takes a hit. Russia can withstand a dip in price by as much as $20 per barrel; but worries would surface should the $90-resistance be broken. To put things into perspective, around 85% Russia's oil is sold to EU buyers.

Finally, there is the issue of Ukraine as a major transit point for oil & gas, even though it is not a major producer of either. According to JP Morgan Commodities Research over 70% of Russia's oil & gas flow to Europe passes through Ukrainian territory. In short, all parties would take a hit and the risk premium, could just as well turn into a news sensitive risk discount.

Furthermore, in terms of market sentiment, this blogger notes that 90% of the time all of the risk priced and built into the forward month contract never really materialises. So this then begs the question, whose risk is it anyway? The guy at the end of a pipeline waiting for his crude cargo or the paper trader who actually hasn't ever known what a physical barrel is like!

The situation has also made drawing conclusions from ICE's latest Commitments of Traders report a tad meaningless for this week. Speculative long positions by hedge funds and other money managers that the Brent price will rise (in futures and options combined), outnumbered short positions by 139,921 lots in the week ended February 25, prior to the Ukrainian escalation.

For the record, that is the third weekly gain and the most since October 22. Net-long positions rose by 18,214 contracts, or 15%, from the previous period. ICE also said bearish positions by producers, merchants, processors and users of the North Sea crude outnumbered bullish wagers by 266,017 lots, rising 8.2% from the week before.

Away from Ukraine and on to supply diversity, Norway's Statoil has certainly bought cargo from a land far, far away. According to Reuters, Statoil bought 500,000 barrels of Colombian Vasconia medium crude, offered on the open market in February by Canada's Pacific Rubiales.

When a cargo of Columbian crude is sold by a Canadian company to Norwegian one, you get an idea of the global nature of the crude supply chain. That's if you ever needed reminding. The US remains Pacific Rubiales' largest market, but sources say it is increasing its sales to Europe.

Finally, in the humble opinion of yours truly, Vitol CEO Ian Taylor provided the soundbite of the International Petroleum Week held in London last month.

The boss of the world's largest independent oil trading firm headquartered in serene Geneva opined that Dated Brent ought to broaden its horizons as North Sea production declines. The benchmark, which currently includes Brent, Forties, Oseberg and Ekofisk blend crudes, was becoming "less effective" according to Taylor.

"We are extremely concerned about Brent already not becoming a very efficient or effective benchmark. It’s quite a concern when you see that production profile. Maybe the time has come to really broaden out Dated Brent," he said.

Broadening a benchmark that's used to price over half the world's crude could include Algeria's Saharan Blend, CPC Blend from the Caspian Sea, Nigeria's Bonny Light, Qua Iboe and Forcados crudes and North Sea grades DUC and Troll, the Vitol CEO suggested.

Taylor also said Iran wasn't going to be "solved anytime soon" and would stay just about where it is in terms of exports. The Oilholic couldn't agree more. That's all for the moment folks! Keep reading, keep it 'crude'! 

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© Gaurav Sharma 2014. Photo: Pipelines & gas tank, Russian Federation © Rosneft (TNK-BP archives)

Saturday, January 18, 2014

Notes on a scandal from an ex-Enron pragmatist

When the Enron scandal broke and that icon of corporate America filed for bankruptcy on December 1, 2001, the Oilholic was as stumped by the pace of events as those directly impacted by it. In the months and years that were to follow, bankruptcy proceedings for what was once 'America's Most Innovative Company' according to Fortune, turned out to be the most complex in US history.

It soon emerged that one of Enron's own – Dr Vincent Kaminski – a risk management expert especially headhunted in 1990s from Salomon Brothers and appointed Managing Director for Research, had repeatedly red flagged practices within the energy company's corridors of corporate power.

Alas, in a remarkably stupendous act, Kaminski and his team of 50 analysts, while specifically hired to red flag were often ignored when and where it mattered. Cited cautions ranged from advising against the use of creative accounting, "terminally stupid" structuring of Enron's special purpose vehicles (SPVs) to conceal debt by then CFO Andrew Fastow, and the ultimately disastrous policy of securing Enron's debt against stock in the corporation itself.

What transpired has been the subject of several books – some good (especially Elkind & McLean's), some bad and some opportunistic with little insight despite grandiose pretensions to the contrary. Having lapped all of these up, and covered the scandal in a journalistic capacity, the Oilholic had long wanted to meet the former risk manager of Enron.

At last, a chance encounter in 2012, followed by a visit to Houston last November, finally made it possible. These days Kaminski is an academic at Rice University and has written no less than three books; the latest one being on energy markets. Yet, not a single one on the Enron fiasco, one might inquire, for a man so close to it all?

At peace and reasonably mellow in the Houston suburb of The Woodlands, which he calls home, the former Enron executive says, even though it rankles, the whole episode was "in the past", and despite what was said in the popular press – neither was he the only one warning about impending trouble ahead nor could he have altered Enron's course on his own.

"A single person cannot stop a tanker and I wasn't the only insider who warned that there were problems on the horizon. Looking back, I always approached every problem at Enron in good faith, gave the best answers I could come up with on risk scenarios, based on the information I had and my interpretation of it, even if bosses did not like it.

"If honesty was deemed too candid or crude then so be it! Whatever I did at Enron, the red flags I raised, was what I was paid for. Nothing less could have been expected of me; I saw it as my fiduciary duty."

He agrees that Enron's collapse was a huge blow to Houston's economy and overall wellbeing at the time. "There was a chain reaction that affected other parts of the regional economy. In fact, energy trading and marketing itself went through a crisis which lasted a few years."

To this day, Kaminski says he has no way of knowing whether justice was done or not and isn't alone in thinking that. "By the time of the final winding-up process, Enron had about 3,000 entities created all over the world. It was an extremely complex company."

But does the current generation of Rice University students ask him about Enron? "Right now, I am teaching a different generation. Most of my students are typically 25 to 30 years old. When the Enron scandal unfolded [over a decade ago] they were teenagers. A lot has happened in the corporate world since then, which they have had to take in as they've matured. The financial tsunami that was the global financial crisis, and what emerged in its wake, dwarfed what happened at Enron. For them, Enron is but a footnote in corporate history."

"That scandal devastated public trust in one brand, however big it may have been at the time. But the global financial crisis eroded public trust in an entire sector – investment banking. Perhaps as a result, Enron's collapse has ceased to generate as much interest these days. That's a pity! Depending on one's point of view, the extent of the use [or misuse] of SPVs and the number that was discovered at collapsing financial institutions in 2007-09, was several times over what was eventually catalogued at Enron."

Hence, the ex-Enron executive turned academic doubts whether the world really learnt from the scandal. "Enron was a warning from history, from the energy business to other sectors. I describe my former employer as a canary in a coal mine demonstrating the dangers of excessive leverage, of having a non-transparent accounting system and all those sliced and diced SPVs."

"Pre-crisis, the financial sector was guilty of formally removing 'potentially' bad assets from the parent company to SPVs. However, in real financial terms that wasn't the case. When things took a turn for the worse, all the assets and liabilities put on to SPVs came back to be reabsorbed into the balance sheets."

Formally they were separate and 'special', Kaminski notes, but for all practical reasons there was no effective transfer of risk.

"Rewind the clock back and there was no effective transfer of risk in the case of Enron either when its horror story of SPVs and creative accounting came out in all its unsavoury detail. So if lessons were learnt, where is the evidence? Now, let's forget scruples for a moment and simply take it as a basic mistake. Even so, there is no evidence lessons were learned from the Enron fiasco."

He adds that those who don't have an open mind will never learn. "This is not exclusive to the energy business or financial services. It's perhaps true of everything in life. Arrogance and greed also play a part, especially in the minds of those who think they can somehow extricate themselves when the tide turns."

As early as 2004-05, the Rice University academic says he was debating with colleagues that a financial crisis could be on the horizon as the US property market bubbled up.

"Some people branded me as crazy, some called me pessimistic. They said the world is mature enough to manage the situation and progress in economic and financial sciences had created tools for effective management of market and credit risks. Some even agreed that we'll have a train wreck of a global economy, but to my amazement remarked that they knew how to "get out in time."

Kaminski says while it can be true of individuals who can perhaps get out in time, it cannot be true of large corporations and the entire financial system. "They would invariably take a hit, which in some cases – as the financial crisis showed – was a fatal hit. Furthermore, the financial system itself was scarred on a global scale."

Over the years, this blogger has often heard Kaminski compare chief risk officers (CROs) to food tasters in medieval royal courts.

"Indeed, being a risk manager is a job with limited upside. You cannot slow 'acting poison' and the cooks don’t like you as you always complain that the food tastes funny. So if they catch you in a dark place, they will rough you up!" he laughs.

"I have said time and again that risk managers should be truly independent. In a recent column for Energy Risk, I gave the example of the CRO at Lehman Brothers, who was asked to leave the room when senior executives were talking business. It is both weird and outrageous in equal measure that a CRO would be treated in this way. I would resign on the spot if this happened to me as a matter of principle."

He also thinks CROs should be reporting directly to the board rather than the CEO because they need true independence. "Furthermore, the board should not have excessive or blind confidence in any C-suite executive just because the media has given him or her rock-star status."

A switch from the corporate world to academia has certainly not diminished Kaminski’s sense of humour and knack for being candid.

"Maybe having your CEO on the cover of Business Week [Cue: Enron's then CEO Jeff Skilling] could be the first warning sign of trouble! The second signal could be a new shining tower [see above left - what was once Enron’s is now occupied by a firm Skilling called a 'dinosaur' or legacy oil company – Chevron] and the third could be your company's name on a stadium! Our local baseball team – Houston Astros – called a stadium that was 'Enron Field' their home, then 'Enron Failed'. Thankfully, it's now shaken it off and is simply Minute Maid Park [a drinks brand from Coca-Cola's portfolio]."

"But jokes apart, excessive reliance or confidence in any single individual should be a red flag. I feel it's prudent to mention that I am not suggesting companies should not reward success, that's different. What I am saying is that the future of a company should not rely on one single individual."

Switching to 'crude' matters, Kaminski says trading remains an expensive thing for energy companies and is likely to get even costlier in light of higher capital requirements for registering as a swap dealer and added compliance costs. "So the industry will go through a slowdown and witness consolidation as we are already seeing."

On a more macro footing, he agrees that the assetization of black gold will continue as investors seek diversity in uncertain times. As for the US shale bonanza versus the natural gas exports paradigm, should exports materialise in incremental volumes, the [domestic] price of natural gas will eventually have to go up stateside, he adds.

"Right now, the price [of US natural gas] is low because it is abundant. However, to a large extent that abundance is down to it being cross-subsidised by the oil industry [and natural gas liquids]. I believe in one economic law – nothing can go on forever.

"As far as the LNG business is concerned, it will still be a reasonably good business, but not with the level of profitability that most people expect, once you add the cost of liquefaction, transportation, etc."

The Oilholic and the ex-Enron pragmatist also agreed that there will be a lot of additional capacity coming onstream beyond American shores. "We could be looking at the price of natural gas in the US going up and global LNG prices going down. There will still be a decent profit margin but it's not going to be fantastic," he concludes.

And that's your lot for the moment! It was an absolute pleasure speaking to Dr Kaminski! Keep reading, keep it 'crude'!

To follow The Oilholic on Twitter click here.


© Gaurav Sharma 2014. Photo 1: Dr Vincent Kaminski at El Paso Trading Room, Rice University, Houston. Photo 2: Chevron Houston, formerly the Enron Towers. Photo 3: Dr Kaminski & the Oilholic, in The Woodlands, Texas, USA © Gaurav Sharma, November 22, 2013.

Wednesday, December 04, 2013

OPEC holds quota at 30 mbpd, El-Badri stays on

We’ve been here before dear readers, we’ve been here before. Main headline at the conclusion of the 164th OPEC conference here in Vienna is a familiar one. OPEC’s production quota stays at 30 million barrels per day and Secretary General Abdalla Salem El-Badri – long overdue to step down – stays on in his post, as member nations torn between Iranian and Saudi tussles fail to agree on a candidate for the post. So at the end of it all a battle-weary El-Badri, took the stage as usual. Not entirely bereft of a sense of humour, the secretary general had a few quips, the odd joke, brushed off scribes pokes to say that the cartel had considered the global economic outlook which remains “uncertain with the fragility of the Euro-zone remaining a cause for concern.”
 
“We was also noted that, although world oil demand is forecast to increase during the year 2014, this will be more than offset by the projected increase in non-OPEC supply. Nevertheless, in the interest of maintaining market equilibrium, the OPEC decided to maintain the current production level of 30 million bpd.”
 
In taking this decision, OPEC said it had reconfirmed its members’ readiness to swiftly respond to developments which could have an adverse impact on the maintenance of an orderly and balanced oil market.
 
El-Badri's tenure as Secretary General carries on for a period of one year, with effect from January 1, 2014. As the Oilholic noted in an earlier post, OPEC had a chance to send a message but missed a trick here. Despite the threat of incremental non-OPEC barrels, it failed to present a united front leaving El-Badri to carry the can in front of the world’s press and fly the OPEC flag.
 
The man himself though had a thing or two to say or avoid saying. Coming on the latter bit first, El-Badri declined comment on what increasing Iranian production would mean for the overall production quota. He also described incremental non-OPEC supply as "good for global consumers", acknowledged OPEC’s concerns about shale and said he was monitoring the supply side situation.
 
Yet later, he cut short an analyst’s question saying people should not “exaggerate” the impact of incremental or additional project barrels. “You keep going down this track and very soon you will see both prospective and thriving E&P jurisdictions lose their appetite for investing in new fields and enhancing existing facilities.” The Oilholic thinks the Secretary General has a point, albeit the point itself is a bit exaggerated.
 
One key theme to emerge was that OPEC members’ focus for exports was firmly to the East now. Several delegates and El-Badri himself acknowledged that supplies heading to the US – especially from Nigeria, Angola and Venezuela – were being diverted to far Eastern markets. The US it seems “wasn’t a priority” for OPEC in the first place; it’s even less so now. That's your lot from OPEC HQ! Keep reading, keep it ‘crude’!
 
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© Gaurav Sharma 2013. Photo: OPEC Secretary General Abdalla Salem El-Badri at the conclusion of 164th OPEC meeting of ministers in Vienna, Austria © Gaurav Sharma December 4, 2013.

The acknowledgement: OPEC flags-up US output

There should be no shock or horror – it was coming. Ahead of taking a decision on its production quota, president of the 164th OPEC conference Mustafa Jassim Mohammad Al-Shamali, who is also the deputy prime minister and minister of oil of Kuwait, openly acknowledged the uptick in US oil production here in Vienna.
 
“In the six months that have passed since the Conference met here in Vienna in May, we have seen an increasingly stable oil market, which is a reflection of the gradual recovery in the world economy. This positive development stems mainly from a healthy performance in the US, in addition to the Eurozone countries returning to growth,” Al-Shamali told reporters in his opening remarks.
 
It follows on from an acknowledgement by OPEC at its last summit in May about the impact of shale, which up and until then it hadn’t. But the latest statement was more candid and went further. “Non-OPEC oil supply is also expected to rise in 2014 by 1.2 million barrels per day (bpd). This will be mainly due to the anticipated growth in North America and Brazil,” Al-Shamali added.
 
You can add Canada and Russia to that mix as well even though the minister didn’t.
 
Turning to the wider market dynamics, Al-Shamali said that although the market had started to gradually emerge from the tough economic situation of the past few years, the pace of world economic growth remains slow. “Clearly, there are still many challenges to overcome.”
 
Finally, a few footnotes before the Oilholic takes your leave for the moment. Here is the BBC’s take why OPEC is losing control of oil prices due to US fracking – not entirely accurate but largely on the money. Meanwhile, Nigerian oil minister Diezani Alison-Madueke has just told Platts that her country supports OPEC’s current 30 million bpd crude output ceiling, at least for the next few months until the group's next meeting.
 
Alison-Madueke also said she was keen to see how OPEC saw the impact of the US shale oil and gas boom on itself. "We would like to see that we continue with volumes we have held for the last year or so at least between now and the next meeting. I think that would be a good thing. We would like to see a review of the situation referencing the shale oil and gas to see where we are at this stage as OPEC among other things."
 
Earlier, the Saudi oil minister Al-Naimi poured cold water over the idea of a production cut lest some people suggest that. He sounded decidedly cool on the subject at this morning's media scrum. So that’s three of the ministers saying the quota is likely to stay where it was. The Oilholic would say that removes all doubt. That's all from OPEC HQ for the moment folks, more from Vienna later as we gear up for an announcement! Keep reading, keep it ‘crude’! 
 
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© Gaurav Sharma 2013. Photo: OPEC media briefing room, Vienna, Austria © Gaurav Sharma 2013.

Thursday, November 21, 2013

‘Frackers’ & US coffers plus other crude matters

US Interior Secretary Sally Jewell should be a happy bunny this week say contacts in Houston town. In fact since morning, no fewer than nine have pointed this out to The Oilholic.

That is because Jewell's Interior Department has collected and disbursed over US$14.2 billion this week courtesy of a record royalties and fees windfall from oil & gas drilling on public land and US territorial waters for the fiscal year ending September 30. The figure is the second-highest collection on file and represents an annualised increase of $2 billion over the last fiscal year.

Fracking and horizontal drilling coupled with increasing interest in offshore E&P are being seen as the drivers. There is one caveat though, the figure does include proceeds of a bonus licensing bid in the Gulf of Mexico that took place in 2012, but was put on ledgers for 2013. In a statement, Jewell said, "The figure reflects significant energy production from public resources in the United States and serves as critical revenue stream for federal and state governments and tribal communities."

While the Interior Secretary stopped short of blessing the frackers, they are chuffed to bits and there is a fair bit of table thumping here. Let's also not forget that despite the frenetic pace of E&P activity in North Dakota, the state of Texas remains the country's largest producer of the crude stuff. That position is likely to be retained on account of fracking, enhanced oil recovery techniques being deployed, horizontal drilling and many established extraction sites that are chugging along nicely.

There is one positive domino effect which is largely going under the radar – Houston is leading the global race in the manufacture and shipping of oil & gas equipment manufacturing from blowout preventers to wellheads. Some of equipment can be loaded conventionally, but the rest – i.e. break bulk (heavy equipment which cannot be shipped in conventional containers) loading is also creating additional revenue streams in the state.

According to the Port of Houston, the facility handles nearly 70% of the US' entire break bulk cargo. Some here say jobs have more than doubled since 2005; Texas (along with North Dakota) also has the lowest unemployment rates in the country to brag about. Recent research conducted by McKinsey and IHS Global Insight came out bullish on the industry's long term potential for job creation – with both forecasting the creation of 1.7 million and 3.9 million jobs by 2020 and 2025 respectively.

Now that tells you something, especially as the US is poised to overtake Russia and Saudi Arabia and become the world's largest producer in barrels of oil equivalent terms. Strangely enough though, some of the majors such as Shell and BHP Billiton have apparently not got it right. The former has cut its shale production projections while the latter has put up half of its oil & gas land holdings right here in Texas as well as New Mexico for sale.

ExxonMobil's exit from shale exploration in Poland has also slightly dented the hypothesis of America exporting its nous on shale overseas. Some geologists have long warned that no one size fits all shale beds! Nonetheless, its early days yet on the knowledge export front at least.

Going beyond Texan borders, the positive impact of major upstream project start-ups on cash generation in the global integrated oil & gas industry in 2014-15, as well as continuing robust crude price conditions, have resulted in a change of outlook for the sector by Moody's to 'positive' from 'stable'. Up until this month, the ratings agency's outlook had been stable since September 2011.

Francois Lauras, senior credit officer in Moody's corporate finance group, said, "With crude prices set to remain robust, we expect that the start-up and ramp-up of major upstream projects over the next 12-18 months will benefit companies' production profiles and operating cash flow generation, and lead the industry's EBITDA to grow in the mid-to-high single digits year-on-year in 2014, albeit with more of the improvement showing in the latter part of the year."

"Downstream operations will remain under pressure, but EBITDA from refining and marketing operations will stabilise near their 2013 levels," he adds. Furthermore, Lauras feels that the global integrated oil and gas sector's capital investment in 2014 will remain close to its record levels of 2013.

The completion of the major upstream projects currently under construction will hold the key to the sector's return to positive free cash flow in the medium term. Integrated oil & gas companies will also continue to manage their asset portfolios actively and will execute further asset sales, supporting their financial profiles, Moody's concluded.

Finally, the Oilholic leaves you with glimpses of The Woodlands (see above, click to enlarge), a suburb of Houston, dedicated by none other than the late George Mitchell, a man credited for pioneering fracking.

Founded in 1974 as a largely residential area, today it houses commercial operations of many companies including those of a crude variety such as Anadarko, Baker Hughes and one GeoSouthern energy, a Blackstone Group backed company. It was one of the first to take a punt on the Eagle Ford shale prospection area and has just sold shale acreage to Devon Energy.

That's all for the moment from Houston folks! Keep reading, keep it 'crude'!

To follow The Oilholic on Twitter click here.


© Gaurav Sharma 2013. Photo 1: Pump Jacks, Perryton © Joel Sartore / National Geographic. Photo 2: Collage of The Woodlands, Texas, USA © Gaurav Sharma, November 2013.