Showing posts with label Dana Petroleum. Show all posts
Showing posts with label Dana Petroleum. Show all posts

Sunday, January 20, 2013

Algeria’s ‘dark cloud’, PDVSA’s ratings & more

The terrorist strike on Algeria’s In Amenas gas field last week and the bloodbath that followed as the country’s forces attempted to retake the facility has dominated the news headlines. The siege ended on Saturday with at least 40 hostages and 32 terrorists dead, according to newswires. The number is likely to alter as further details emerge. The hostage takers also mined the whole facility and a clear-up is presently underway. The field is operated as a joint venture between Algeria's Sonatrach, Statoil and BP. While an estimated 50,000 barrels per day (bpd) of condensate was lost as production stopped, the damage to Algeria’s oil & gas industry could be a lot worse as foreign oil workers were deliberately targeted.
 
In its assessment of the impact of the terror strike, the IEA said the kidnapping and murder of foreign oil workers at the gas field had cast a ‘dark cloud’ over the outlook for the country's energy sector. The agency said that 'political risk writ large' dominates much of the energy market, 'and not just in Syria, Iran, Iraq, Libya or Venezuela' with Algeria returning to their ranks. Some say it never left in the first place.
 
Reflecting this sentiment, BP said hundred of overseas workers from IOCs had left Algeria and many more were likely to join them. Three of the company’s own workers at the In Amenas facility are unaccounted for.
 
Continuing with the MENA region, news emerged that Saudi Arabia’s output fell 290,000 bpd in December to 9.36 million bpd. Subsequently, OPEC’s output in December also fell to its lowest level in a year at 30.65 million bpd. This coupled, with projections of rising Chinese demand, prompted the IEA to raise its global oil demand forecast for 2013 describing it as a 'sobering, 'morning after' view.'
 
The forecast is now 240,000 bpd more than the IEA estimate published in December, up to 90.8 million bpd; up 1% over 2012. "All of a sudden, the market looks tighter than we thought…OECD inventories are getting tighter - a clean break from the protracted and often counter-seasonal builds that had been a hallmark of 2012," IEA said.
 
However, the agency stressed there was no need for rushed interpretations. "The dip in Saudi supply, for one, seems less driven by price considerations than by the weather. A dip in air conditioning demand - as well as reduced demand from refineries undergoing seasonal maintenance - likely goes a long way towards explaining reduced output. Nothing for the global market to worry about," the IEA said.
 
"The bull market of 2003‐2008 was all about demand growth and perceived supply constraints. The bear market that followed was all about financial meltdown. Today's market, as the latest data underscore, has a lot to do with political risk writ large. Furthermore, changes in tax and trade policies, in China and in Russia, can, at the stroke of a pen, shakeup crude and products markets and redraw the oil trade map," the agency concluded.
 
Simply put, it’s too early for speculators to get excited about a possible bull rally in the first quarter of 2013, something which yours truly doubts as well. However, across the pond, the WTI forward month futures contract cut its Brent discount to less than US$15 at one point last week, the lowest since July. As the glut at Cushing, Oklahoma subsides following the capacity expansion of the Seaway pipeline, the WTI-Brent discount would be an interesting sideshow this year. 
 
The IEA added that non-OPEC production was projected to rise by 980,000 bpd to 54.3 million bpd, the highest growth rate since 2010. Concurrently, BP said that US shale oil production is expected to grow around 5 million bpd by 2030. This, according to the oil major, is likely to be offset by reductions in supply from OPEC, which has been pumping at historical highs led by the Saudis in recent years.
 
BP's chief economist Christof Ruehl said, "This will generate spare capacity of around 6 million bpd, and there's a fault line if there is higher shale production then the consequences would be even stronger." But the shale revolution will remain largely a "North American phenomenon," he added.
 
"No other country outside the US and Canada has yet succeeded in combining these factors to support production growth. While we expect other regions will adapt over time to develop their resources, by 2030 we expect North America still to dominate production of these resources," Ruehl said.
 
Along the same theme, CNN reported that California is sitting on a massive amount of shale oil and could become the next oil boom state. That’s only if the industry can get the stuff out of the ground without upsetting the state's powerful environmental lobby. Yeah, good luck with that!

Returning to Saudi Arabia, Fitch Ratings said earlier this month that an expansionary 2013 budget based on a conservative oil price will support another year of healthy economic growth for the country and a further strengthening of the sovereign's net creditor position. However, overall growth will slow “due to a decline in oil production that was already evident in recent months.”
 
In the full year to December-end 2013, the Saudi budget, unveiled on December 29, projected record spending of US$219 billion (34% of GDP), up by almost 20% on the 2012 budget. Budgeted capital spending is 28% higher than in 2012, though the government has struggled to achieve its capital spending targets in recent years.
 
While an 18% rise in Saudi revenues is projected in the budget, they are based on unstated oil price and production assumptions, with the former well below prevailing market prices. Fitch anticipates Saudi production and prices will be lower in 2013 than 2012.

"With no new revenue-raising measures announced and little scope for higher oil revenues, the revenue projection appears less cautious than usual. However, actual revenues generally substantially exceed budget revenues (by an average of 82% over the past five years) and should do so again in 2013," the agency said.
 
Meanwhile, political uncertainty continues in Venezuela with no clarity about the health of President Hugo Chavez. It has done Petróleos de Venezuela's (PDVSA), the country’s national oil company, no favours. On January 16, ratings agency Moody’s changed PDVSA's rating outlook to negative.

It followed the change in outlook for the Venezuelan government's local and foreign currency bond ratings to negative. "The sovereign rating action reflects increasing uncertainty over President Chavez's political succession, and the impact of a possibly tumultuous transition on civil order, the economy, and an already deteriorating government fiscal position," Moody’s said.
 
On PDVSA, the agency added that as a government-related issuer, the company's ratings reflect a high level of imputed government support and default correlation between the two entities. Hence, a downgrade of the government's local and foreign currency ratings would be likely to result in a downgrade of PDVSA's ratings as well.
 
Away from a Venezuela, two developments in the North Sea – a positive and a negative apiece – are worth taking about. Starting with the positive news first, global advisory firm Deloitte found that 65 exploration and appraisal wells were drilled on the UK Continental Shelf (UKCS), compared with 49 in 2011.
 
The activity, according to Deloitte, was boosted by a broader range of tax allowances and a sustained high oil price. The news came as Dana Petroleum said production had commenced at the Cormorant East field which would produce about 5,500 bpd initially. Production will be processed at the Taqa-operated North Cormorant platform, before being sent to BP's Sullom Voe terminal (pictured above) for sale.
 
Taqa, an Abu Dhabi government-owned energy company, has a majority 60% stake in the field. Alongside Dana Petroleum (20%), its other partners include Antrim Resources (8.4%), First Oil Expro (7.6%) and Granby Enterprises (4%).
 
While Taqa was still absorbing the positives, its Cormorant Alpha platform, about 160 km from the Shetland Islands, reported a leak leading to a production shut-down at 20 other interconnected North Sea oilfields.
 
Cormorant Alpha platform handles an output of about 90,000 bpd of crude which is transported through the Brent pipeline to Sullom Voe for dispatch. Of this only 10,000 bpd is its own output. Thankfully there was no loss of life and Taqa said the minor leak had been contained. It is currently in the process of restoring 80,000 bpd worth of crude back to the Brent pipeline system along with sorting its own output.
 
Finally, as the Oilholic blogged back in October on a visit to Hawaii, Tesoro is to close its Kapolei, O'ahu refinery in the island state in April as a buyer has failed to turn-up (so far). In the interim, it will be converting the facility to a distribution and storage terminal in the hope that a buyer turn up. The Oilholic hopes so too, but in this climate it will prove tricky. Tesoro will continue to fulfil existing supply commitments.
 
That’s all for the moment folks except to inform you that after resisting it for years, yours truly has finally succumbed and opened a Twitter account! Keep reading, keep it ‘crude’!
 
To follow The Oilholic on Twitter click here.
 
© Gaurav Sharma 2013. Photo: Sullom Voe Terminal, BP © BP Plc.

Friday, July 13, 2012

Brent & the ‘crude’ fortnight to Friday the 13th!

Despite crude economic headwinds, the Brent forward month futures price spiked back well above US$100 per barrel on July 3. No one was convinced it’d stay there and so it proved to be barely a week later. Since then it has lurked around the US$100 mark. Our crude friends in the trading community always like to flag up supply shocks – some real some and some perceived along with some profit taking thrown in the mix.

The Norwegian oil industry strike which began on June 24 was a very real threat to supply. When oil industry workers down tools in a country which is the world’s fifth largest exporter of the crude stuff, then alarm bells ought to ring and so they did. Being a waterborne crude benchmark, Brent was always likely to be susceptible to one of its main production sources. The Louisiana Light’s fluctuation over the hurricane season stateside would be a fair analogy for the way Brent responded to the news of the strike.

Quite frankly, forget the benchmark; the strike saw Norwegian oil production dip by 13% and its gas output by 4% over the 16 days that it lasted. So when a Reuters report came in that Norway's government had used emergency powers to step in and force offshore oil and gas workers back to work, more than the bulls eased off.

The dispute, which is by no means over, concerns offshore workers' demand for the right to retire early, at 62, with a full pension. The row revolves around the elimination of a pension add-on introduced in 1998 for workers who retire (at 62), five years ahead of Norway's official retirement age and three years ahead of the general age for oil workers.

Accompanying a very real supply shock in the shape of the Norwegian strike were empty threats from Iran to close the Strait of Hormuz in wake of the EU sanctions squeeze. Traders put two and two together and perhaps came-up with 22 out of a sense of mischief.

First of all, the Iranians would be mighty silly if they decided to close the Strait of Hormuz with the US Fifth fleet lurking around. It just would not work and Iran would hurt itself more for the sake of what would at best be a temporary disruption. Secondly, City estimates, for instance the latest one being put out by Capital Economics, suggest that the US and EU sanctions could ultimately reduce oil exports from Iran by as much as 1.5 million barrels per day (bpd).

While it is serious stuff for Iran, the figure is less than 2% of global supply. As such hardly anyone in the City expects the implementation of sanctions on Iran to be a game-changer from a pricing standpoint.

“We maintain our view that the imminent tightening of Western sanctions on Iran is unlikely to have anywhere near as large an impact on global oil prices as many had feared. Demand is weakening and other suppliers are both able and willing to meet any shortfall. Admittedly, much could still depend on how the Iranian regime chooses to respond,” said Julian Jessop of Capital Economics.

Causative effect of such a market sentiment predictably sees Brent back in US$90s to lower US$100 range. In fact Capital Economics, Société Générale, Moody’s and many other forecasters have a US$70-100 per barrel forecast for Brent for the remainder of the year.

A spokesperson for Moody’s told the Oilholic that the agency has lowered its crude price assumptions to US$100/barrel for Brent and US$90/barrel for WTI in 2012, with an additional expected decline to US$95/barrel for Brent and US$85/barrel for WTI in 2013.

Moody's also expects that the spread between benchmark Brent and WTI crude will narrow to about US$5 in 2014. In a report, the agency adds that a drop in oil prices and jitters over economic conditions in Europe, the US and China suggest the global exploration and production sector (E&P) will see its earnings grow more slowly over the next 12 to 18 months.

As such, Moody's expects E&P industry EBITDA to grow in the mid-to-high single digits year on year through mid-2013. Expectations for EBITDA growth in the sector above 10% would suggest a positive outlook, while a retreat of 10% or more would point to a negative outlook. Moody's changed its outlook for the E&P industry to stable from positive on June 27, 2012.

The agency also expects little change in US natural gas prices before the end of 2013 with a normal winter offering the best near-term support for natural gas prices as increased utility and industrial demand will ramp up slowly.

On the corporate front, in an interesting fortnight Origin Energy announced that the Australia Pacific LNG project (APLNG) – in which its stake is at 37.5% after completion of Sinopec's additional equity subscription – has received board approval for Final Investment Decision (FID) for the development of a second LNG train.

The expanded two-train project is expected to cost US$20 billion for a coal seam gas (CSG) to liquefied natural gas (LNG) project in Queensland, Australia. Elsewhere, India’s Essar Energy subsidiary Essar E&P Ltd is to sell a 50% stake in Vietnam's offshore gas exploration block 114 to Italy’s ENI.

Under the terms of the transaction, which is still subject to approval from the Vietnamese government, ENI is also assuming operator status for the block. Yours truly guesses the Indian company finally decided it was time to indulge in a bit of risk diversification.

Continuing with corporate stuff, the Oilholic told you BP’s planned divestment in TNK-BP won’t come about that easily or smoothly. One of its oligarch partners - Mikhail Fridman - has alleged that there are no credible buyers for BP’s 50% stake in the dispute ridden Russian venture.

In an interview with the Wall Street Journal on June 29, Fridman said, "We doubt it has any basis in fact. They are trying to buy time, to reassure investors."

However, BP said it stood by its announcement. It also announced an agreement to sell its interests in the Alba and Britannia fields in the British sector of the North Sea to Mitsui for US$280 million. The sale includes BP’s non-operating 13.3% stake in Alba and 8.97% stake in Britannia. Completion of the deal is anticipated by the end of Q3 2012, subject to UK regulatory approvals.

Net production from the two fields averages around 7,000 barrels of oil equivalent per day. It is yet another example of BP’s smart management of its asset portfolio in wake of Macondo as the company refocuses on pastures and businesses new.

Elsewhere in the North Sea, Dana Petroleum expects to start drilling at two new oil fields off Shetland named - Harris and Barra – by Q2 2013. The first crude consignment from what’s described as the Western Isles project will come onstream in 2015. A spokesperson said field production could run for 15 years.

The region needs all the barrels it can pull as the UK’s budgetary watchdog – the Office for Budget Responsibility (OBR) – has projected that future oil and gas revenues from the North Sea may be much lower than previous forecasts.

OBR sees the Brent prices rise from US$95/barrel in 2016 to US$173/barrel in 2040. “This compares lower with a projection in our assessment last year of a rise from US$107/barrel in 2015, rising to US$206/barrel in 2040," a spokesperson said.

As a result the OBR now projects tax receipts will be about 0.05% of GDP by 2040-41; half the level it projected in last year. It identified lower projected oil and gas prices as the key driver for the reduced figures given this year. The Oilholic won’t be called upon to vote on Scottish independence; but if yours truly was a Scottish Nationalist then there’d be a lot to worry about.

Finally, it looks like UK regulator – the Takeover Panel – has had enough of the protracted battle for the takeover of Cove Energy between Royal Dutch Shell and Thailand's PTTEP. It has given both parties a deadline of July 16 to make their final offers.

The Takeover Panel announced on Friday 13, July 2012 that if no offer is accepted by the said date, the sale of Cove will be decided by an auction on July 17. It could be lucky for neither, if they pay over the odds. That’s all for the moment folks. Keep reading, keep it ‘crude’!

© Gaurav Sharma 2012. Photo: North Sea oil rig © Cairn Energy.

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