David Fuller and Eoin Treacy's Comment of the Day
Category - Energy

    OPEC Meeting Review

    Thanks to a subscriber for this report from DNB which may be of interest. Here is a section: 

    OPEC has just decided a headline cut of 1.2 million b/d

    We calculate that compared with October secondary sources in the OPEC report, the net OPEC cut from the 11 participating countries in the deal is 0.982 million b/d

    Angola was allowed to use September output as the base instead of October

    The cartel will use secondary sources to monitor output reductions
    Indonesia, Libya and Nigeria is not part of the deal

    Since the cartel has distributed quotas to the different countries, have organized a monitoring committee and are using secondary sources, the deal is very bullish to the oil price

     

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    Collision Course

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    While energy market watchers have highlighted President-Elect Trump’s nod towards drilling and fracking, we believe that a Trump administration will have a larger impact on the US demand side of the ledger. The two key regulations which, if repealed, could drive US gasoline demand materially higher are the Corporate Average Fuel Efficiency Standards (CAFE) and the Renewable Fuel Standard (RFS). The potential impact of a Trump presidency on US gasoline demand is not one that should be underestimated. After all, US gasoline demand comprises of nearly 10% of total global oil demand and has been the sole bright spot in the OECD region, which has otherwise been trending lower on a structural basis since the recession. The potential repeal of aforementioned regulations is unlikely to make a difference in his first 90 days in office, but it is a rather bullish potential catalyst in the quarters and years to come.

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    Musings from the Oil Patch November 15th 2016

    Thanks to a subscriber for this edition of Allen Brooks’ ever interesting report for PPHB. Here is a section:

    Another issue that has yet to be addressed is a proposed ban on oil tankers operating off British Columbia’s coastline that would effectively shut down the development of an oil export terminal at Kitimat and thus kill the proposed Enbridge (ENB-NYSE) Northern Gateway oil export pipeline. If the tanker ban is put in place, it will force the development of the Trans Mountain pipeline as the primary West Coast oil export pipeline. That would leave the Trudeau government to deal with TransCanada Corp.’s (TRP-NYSE) Energy East oil pipeline project to move Western Canadian oil to the East Coast where it could be exported to the U.S. East Coast or Europe. Despite being the “environmental” prime minister, Mr. Trudeau is recognizing that without more oil and gas export opportunities, his nation’s economy, which depends on a healthy energy economy, will suffer with many social and financial repercussions.

    The Canadian federal government’s decision about Trans Mountain on December 19th will be an important milestone for the nation’s energy business. There are still numerous other policy decisions that must be addressed before Canada develops a full-scale oil and gas export expansion regime, but the first steps appear to have been taken last week.

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    Is the EV finally coming of age?

    This article by Scott Collie for Gizmag may be of interest to subscribers. Here is a section:

    One important breakthrough will be increasing the energy density of the battery through being able to cram more cells into the same volume of battery packs. The battery density doubled between 2009 and 2016, and this is definitely not the end. Just like with the technological development of the personal computer, there is something similar to a 'Moore's Law' in the battery development: currently, we recognize an annual improvement rate of 14 percent, which is quite immense."

    Although 14 percent is significant, it's only just a start when it comes to battery technology. At the moment, electric cars make use of lithium-ion batteries, the type pioneered by the Tesla Roadster back in the mid-2000s. Schenk says there's plenty of improvement to come in lithium-ion tech, but greater leaps forward are in the pipe.

    "New technologies, and especially those aimed at material-related improvements, plus ever-increasing production volumes leading to further price decreases, will determine the development stages of the next few years," Schenk says. "Within the next decade a major technological leap is expected with lithium-sulphur systems, and these are set to revolutionize costs and operating range as extraordinarily relevant buying criteria for electric vehicles."

    Already, improvements to battery chemistry are starting to pay off, and people are starting to buy electric vehicles in greater numbers. Renault, one of the largest players in the European electric game, sold 23,087 electric cars in 2015 - a 49 percent increase on its 2014 numbers.

     

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    Musings from the Oil Patch November 1st 2016

    Thanks to a subscriber for this edition of Allen Brooks' ever interesting report for PPHB which may be of interest. Here is a section:

    It appears to us that everyone in the energy industry is fixated on whether the OPEC oil ministers meeting in Vienna, Austria on November 30th will produce an agreement to limit the group’s output, and how that production volume will be shared among the group’s 12 members. Also, it will be important to see who among the 12 OPEC members will be exempted from a monthly production quota and what those countries near-term output goals are. Lastly, we need to see some support from Russia for OPEC’s production cap to have much strength. While all these details are important to the outcome of the OPEC meeting and how the energy world reacts to whatever is agreed to, the lack of executive thinking about what happens to energy demand if the U.S. enters a recession could be the pothole everyone steps in. The duration and depth on any recession will determine how much oil demand might be lost due to weaker economic activity. We suggest you should pay attention to this hidden elephant in the OPEC meeting room. 

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    OPEC May Need Help to End the Global Glut of Oil

    This article by Grant Smith for Bloomberg may be of interest to subscribers. Here Is a section:  

    If OPEC reduces output to 32.5 million barrels a day -- a cut of 900,000 a day from September levels -- it would be pumping slightly less than the amount needed to meet demand in 2017, the group’s monthly report from Oct. 12 shows. Inventories would contract as a result, but only by 36.5 million barrels over the course of the year, a negligible impact on a stockpile surplus the group estimated at 322 million barrels above the five-year average in August.

    If OPEC doesn’t act to reduce stockpiles next year, Societe Generale’s price forecasts would probably have to be revised lower, Mike Wittner, head of oil-market research, said in an e-mailed note. Over the first three quarters of 2017, the bank currently sees Brent averaging $55 a barrel and West Texas Intermediate at $53.50.

     

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    Is the Deepwater Dead?

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    Marky Mark-ing to market cost and efficiency gains: More competitive than you think
    Contrary to popular belief, the US onshore isn’t the only sector seeing meaningful cost deflation and/or efficiency gains. While the ~60% reduction in DW rig rates has grabbed headlines, broad improvements, including drill-days (-30%-40%), steel costs (-30%), and various SURF/topsides costs (-10%-30%) have reduced total project costs by 30%-40%, in our view. And given the lag in response time, excess capacity and a moderate pick-up in activity, we expect cost and efficiency gains to be more durable than in the US onshore.

    But not all barrels are created equal. Only high quality resource can compete While all deepwater tends to get lumped together, the range of economics across projects is diverse (sub $30/bbl-$80+/bbl breakevens), with only high quality resource set to compete. We examine various drivers of project economics, many poorly understood, including fiscal terms, resource size, resource density, and proximity to infrastructure, and potential impact. We see high quality, pre-FID deepwater projects breaking even at roughly $40-$50/bbl.

    Meaningful challenges remain
    Though more competitive than the market believes, meaningful challenges will continue to drive an increasing share of discretionary capital to US shale, including: geologic risk, project execution risk, geopolitical risk, and capital inflexibility. Adjustments to development strategies and scope can mitigate some risk, and large, diverse IOC budgets will invest across the spectrum, but failure to revolve would demand a higher rate of return, with an increase to 15% required IRR (vs. 10%) increasing average breakevens by $7.5/bbl.

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    All eyes on the spending cap

    Thanks to a subscriber for this note from Deutsche Bank focusing on the Brazilian market. Here is a section:

    Speaking at the Senate Economic Committee on Tuesday, BCB President Ilan Goldfajn. Goldfajn repeated several statements that had already been published in the central bank’s Inflation Report last week, reaffirming the intention of making inflation converge to the 4.5% target in 2017. Goldfajn also repeated the remarks published in the Inflation Report about the three conditions for the authorities to initiate an easing cycle (namely limited persistence of food price shock, disinflation of IPCA components, and lower uncertainty about the fiscal adjustment implementation). The Goldfajn, however, added that the BCB “does not have a pre-established timetable for monetary easing,” as the COPOM decision will depend on several factors, including inflation expectations and forecasts. This comment suggests that the BCB has not yet made a final decision to cut rates, perhaps because market inflation expectations for 2017 have not converged to the 4.1% target yet. Despite Goldfajn’s cautious remarks, we still expect the COPOM to cut the SELIC rate by 25bps at the next meeting later this month.

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    Adobe Expertly Balances Growth and Profitability

    This article from MorningStar following Adobe’s results on September 20th may be of interest to subscribers. Here is a section:

    Third-quarter revenue rose 26% year over year to $1.46 billion, driven by 51% growth in the firm’s subscription revenue base. Creative Cloud continues to serve as the company’s key revenue driver, as both greenfield customers and cloud migrators are providing a consistent lift in the annual recurring revenue base. We believe ample growth opportunities remain across both Creative Cloud and Digital Marketing, particularly as consumer users migrate and enterprise customers consolidate digital content creation and marketing spend around suites of applications versus point solutions.

    The company is beginning to show the two main benefits of renewal billings in its subscriber base, which are higher prices and substantially lower customer acquisition costs. As a result, GAAP operating margin exceeded our forecast by more than 300 basis points at 25%, the firm’s best quarterly mark since the fourth quarter of fiscal 2012. While we suspect the firm will need to maintain aggressive investment in sales and marketing, particularly as competition for digital marketing wins remains intense, we think the increasing renewal mix of Creative Cloud billings will smooth this effect, yielding mid-30s operating margins in the long run.

     

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    Shale Oil Firms Hedge 2017 Prices in 'Droves' After OPEC

    This article by Alex Longley and Javier Blas for Bloomberg may be of interest to subscribers. Here is a section:

    Harry Tchilinguirian, head of commodity research at BNP Paribas SA in London, said on Friday that OPEC had thrown a “lifeline” to U.S. shale firms, prompting them to hedge “in droves.” The bank has “seen many queries coming through” from producers, he said.

    The West Texas Intermediate 2017 calendar strip -- an average of future prices next year that’s often used as a reference for hedging activity -- rose above $50 a barrel to its highest since August on Monday. “When calendar 2017 pricing rises into the low-to-mid $50s, as it is doing now, producer hedging rises materially,” Longson said.

    U.S. shale producers used a similar rally to hedge their prices in May, when the WTI 2017 calendar strip also rose above $50 a barrel. The current activity comes after industry executives told investors in July and August they planned to use any window of higher prices to lock-in cash flows for next year.

    "We would like to be a little bit further hedged than we are today," Pioneer Natural Resources Co. Chief Executive Officer Tim Dove said back in July, noting his company has locked in prices for up to 55 percent of its 2017 exposure. “I’d like to see us get that number up as we go towards at the end of this year.”

     

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