Current Prices Near Lows Even Though Surplus Stocks Revised HigherGlobal macro landscape is brighter, especially with dovish central banks. Oil market rebalancing has temporarily stalled in 3Q16, but it should resume strongly in 4Q with much more robust demand growth. Global supply is declining with sharp declines in non-OPEC crude/condensate more than offsetting increases in non-crude liquids and OPEC crude production. Prices are currently too low and should rally from here. Political risks to supply have turned higher. U.S. crude exports should pick up and contribute to substantial U.S. crude stock draws in August and September. Refinery margins will be weak this autumn as ample light product stocks will be slow to work off.
Conventional wisdom suggests that the cure to low natural gas prices ultimately rests with producers. Yet, despite the record slump in cash prices, Canadian production appears to be defying convention, increasing ~0.3 BCF/D year-on-year during the first half of this year, with producer and midstream companies guiding toward a relatively stable supply outlook ahead. Robust Canadian production underscores the general resilience of North American supply, with slowing WCSB production growth more than offsetting declines from other conventional resources. In contrast to the Lower 48, where take-away pipeline has limited shale growth, only modest declines are taking hold this summer with Canadian production poised to rebound this winter.
An unusually high number of French nukes are offline for maintenance, bringing the load factor of French nuclear down to a multi-year low during July. Assuming nuclear stays at minimum levels of the historical range would bring French prices up to the low €40/MWh during the winter months. The current proposal of the carbon floor is shaping up as a penalty on coal units, which would have a very limited impact on shorter-term prices, but it increases the risks of retirements. The risk of plant closures, with oil units already being retired, makes French prices more likely to move toward Spain and Italy in the medium term. We see the UK market unable to balance for at least 90 hours in the upcoming winter, without calling CBR. Base and peak spark spreads for the winter ahead have surged in anticipation of these risks.
There is wide range in views on the optimal price of carbon — often based on price levels needed to achieve emissions reduction goals. U.S. government estimates of the social cost of carbon utilize a methodology based on academic models that calculate avoided damages. Already used for federal cost-benefit calcs, more recently these estimates have been used in international agreements, for state-level policy, and as a carbon price standard with commercial implications for energy market players. PIRA's report discusses how the social cost of carbon is calculated and used and how modeling choices lead to an estimate that reflects political realities as well as scientific calculations. Implementation of carbon prices generally ends up well below estimates of carbon’s social cost.
While most traders remain focused on production estimates for U.S. corn and soybeans, the wheat market quietly made a 10-year low of $4.035 for the prompt contract last week, and quietly is exactly the way the Non-Commercial shorts like it. The Non-Commercial short in SRW is quickly approaching 145K contracts according to last week’s COT, while the HRW short is nearer 37K contracts. Depending on how you look at some of these numbers the SRW short is probably the third largest in history and may even be at a record currently.
The latest U.S. GDP release disappointed, as it showed the pace of year-on-year economic growth slowing in recent periods. But underlying data suggested that a growth pick-up will materialize soon — after all, a large portion of the recent weakness was due to an inventory drawdown, and this will not continue; and outside of business investment, key activity sectors are in good shape. In the euro area, the pace of second quarter GDP growth matched expectations, and the resilience in business confidence surveys paints an encouraging picture for near-term growth. In South Korea, second quarter growth exceeded expectations, and a recent strengthening in industrial activity is encouraging for the outlook.
Rates in all the major tanker sectors in July have already hit or are fast approaching 2016 lows. Rates are unlikely to improve before the fourth quarter, although fleet capacity growth this year will also limit prospects for a meaningful winter rally.
U.S. ethanol manufacturing margins worsen. RIN generation increases. D6 values near $1.00.
Far East destination markets are rioting against an avalanche of LPG supply in-flows. Cash propane and butane cargo prices plunged last week, well below the newly printed Saudi Contract Prices. The prompt paper arbitrage to the Far East from the Arab Gulf plunged to near zero, indicating that even if freight was free, little money could be made by bringing cargoes to the region. Even more troubling, cash Far East prices are performing even worse, with physical C3 and C4 being called well below August CPs. PIRA believes that the recent glut may be partly due to the recent opening of the new lock system at the Panama Canal. Asia is now being barraged by USGC cargoes, arriving from both the east and west, and canal cargoes (with their significantly shorter voyages) are arriving before cargoes that set out earlier on the Horn of Africa route.
Crude stocks disappoint again, showing a 1.7 million barrel build as imports approach high of year at 8.44 MMB/D. Cushing crude stocks have largest build (1.1 million barrels) since early May. Reported product demand continued to improve, rising 150 MB/D on the week to a strong 20.8 MMB/D.
The prospect of new record-high storage in the U.S. and western Canada raises the risk for a “hard landing” for prices this season. While it appears unlikely that the market will once again probe sub-$2 prices, weakening fundamentals are at odds for sustained $3 prices — with the likelihood of a relapse looming ahead.
On-peak price levels and volatility soared in July amid strong cooling loads. Palo Verde on-peak prices averaged above $40/MWh, up more than $10/MWh from June. Mid-Columbia also gained $10/MWh to average in the low $30s. California hubs saw more modest ($5-6/MWH) gains to the high $30s. Bullish price action at the front of the curve has had relatively little impact on price forecasts with the exception of Palo Verde, where we believe a more bullish stance is justified, particularly for spring/summer 2017. In the near term, however, prices and heat rates are likely to ease as short-term weather forecasts indicate below-normal temperatures in the inland Southwest. In contrast, California heat rates are likely to increase as the call on gas generation reaches its annual peak in August/September amid ongoing gas storage constraints.
The S&P 500 was little changed on the week. Volatility remained low. Emerging market debt and high yield debt pulled back on the week. The dollar was generally weaker, particularly against the yen. It was noticeably stronger against the Russian ruble.
Cape demand is being boosted by improvements in 2Q16 Chinese steel industry numbers and the expansion in Guinean bauxite trade to China. Cape utilization is set to tighten notably in 2H17 and into 2018. Along with stronger bulker prices, PIRA expects a surge in freight rates in 2H17.
Emissions from aviation make up a small share of total global emissions, but they are growing quickly. The International Civil Aviation Organization is expected to unveil a program to keep post-2020 emissions at 2020 levels at its upcoming triennial assembly in September. PIRA estimates that, based on the most recent draft, it could cover at most 60-65% of total global aviation activity — requiring around 2 billion metric tons to be offset between 2021-2035. The main UNFCCC offsetting mechanism (CDM) should meet demand for offsets, but supply risks are related to the need to avoid double-counting of emissions reductions. Compliance costs are expected to make up a small share of jet fuel prices.
The week ending July 22, stocks draw to less than 21 million barrels for the first time in seven weeks. Production drops to 988 MB/D, falling from a record 1,029 MB/D the prior week.
Year-over-year price action similarities in corn have been hard to ignore. Last year, Dec. ’15 corn made a high of $4.5425 in early July. This year’s high of $4.49 was made in mid-June. Last year’s selloff was 97 cents from the highs. This year’s selloff, so far, has been 115.75 cents. Not a perfect match either timing-wise or price-wise, but close enough that a look at last August’s price action is warranted as July comes to a close.
Crude runs rose 81 MB/D on the week, reflecting the restart of Hokkaido. Refinery capacity continues to look underutilized, which suggests discretionary run cuts are occurring. Crude imports moved higher and crude stocks built 1.45 MMBbls. Finished product stocks built by 0.9 MMBbls, mostly due to a rise in naphtha. Refining margins remain very poor and should be inducing discretionary run cuts.
Although the forecast heat will likely limit August stockpiling for the first half of the month, less constructive fundamentals developing in the second half increases the risk of regional congestion. The prospect of new record-high storage in the U.S. and western Canada raises the risk for a “hard landing” for prices this season, with the month-on-month gains recorded in July likely reversing by September.
The emerging growth in Australian LNG output will make less and less room for other LNG supply to push its way into Asia from distant regions. Australia is still only producing 160-mmcm/d (up 90 mmcm/d year-on-year) and remains at a mere 51 % of the total production capacity (315-mmcm/d) it will have in place by 2019.
EIA just released its final monthly May 2016 (PSM) U.S. oil supply/demand data. May 2016 demand came in at 19.20 MMB/D, which showed growth of 85 MB/D, or 0.4%, versus year-ago. Gasoline, kero, and resid all outperformed. Distillate and “other” underperformed. Versus the weeklies, demand was revised lower by 1.1 MMB/D, with "other" revised lower by 627 MB/D, distillate lower by 257 MB/D, and gasoline lower by 213 MB/D. This comes on the heels of an 800 MB/D downward revision in the final April figures, when reported last month. Versus PIRA's Reference Case outlook, May is 450 MB/D less than forecast. End-May total commercial stocks stood at 1,384.1 MMBbls, which was 17.2 MMBbl higher than the preliminaries and 20 MMBbls higher than PIRA had assumed in its balances.
Thursday’s lighter-than-expected U.S. storage build, coupled with an anticipated single-digit addition to inventories for next Thursday’s report, should register as the lightest additions to working gas inventories for the remainder of the cooling season. These relatively low builds have helped propel the newly minted prompt contract beyond $2.90/MMBtu but bely weekly injections thereafter that could easily average 35-40 BCF, as cooling degree days seasonally decline in August.
In the face of sharply warmer-than-normal cooling conditions across most of the eastern and southern U.S., PIRA estimates that U.S. coal stocks are near flat year-on-year at 156 MMst. Though this remains above-normal target levels, some regions are drawing very close to normal seasonal target levels.
Global equities were modestly mixed on the week. Outside the U.S., the markets moved, on balance, higher. The international sectors were led by Japan and Europe, though Norway declined as oil prices weakened. In the U.S., the market was largely unchanged, though technology, retail, and housing moved noticeably higher. Energy lagged and declined on the week.
PIRA's latest update of Asian product demand shows a slowdown in growth from last month but still strong. The deceleration is concentrated in both China and India, but other Asian countries showed improvement, with either stronger growth or smaller year-on-year declines. Data actuals cover the three month period April-June for China, India, Korea, and Japan so this snapshot picks up the most timely data in the largest countries. Overall Asian demand growth slowed from 1.35 MMB/D in the June assessment to just over 1 MMB/D in the latest snapshot.
“New natural gas prices for industrial consumers and other business entities have been increased by 9% on average compared with the prices in June-July 2016, taking into account the price situation on the European natural gas market,” Naftogaz reports. The natural gas prices from the company’s resource are differentiated depending on the volume of purchases, payment conditions and the state of previous payments.
Despite weaker oil prices, the coal market rallied strongly this month. A sizeable drop in China’s domestic coal production from planned curtailments and wet weather saw its thermal coal imports increase again year-on-year in June, while exports supply from other major producing nations has been held in check largely by the weather. PIRA continues to believe that 2017 prices are undervalued despite the increase in pricing this month as stronger oil prices next year will push the curve higher.
Saudi Arabia's formula prices for September were just released. Prices were cut most aggressively to Asia, while U.S. customers saw cuts on the two lightest grades. Prices for delivery into Northern Europe were raised on all grades but the lightest, Arab Extra Light. The adjustments reflect weaker refining economics and narrower light product cracks, particularly in Asia, while the increase in Europe reflects a narrower discount on Urals vs. Dated Brent. The cut in the U.S. was in keeping with a narrowing of the LLS-Mars spread. The bottom line is that Saudi Arabia continues to respond to market conditions so to maintain its market share.
Seasonal gas demand will reach its low point in August, which will relieve some of the pressure on prompt prices and offer additional options for injecting gas on the Continent. Despite this, the run-up in gas prices has not turned away power sector gas demand, helped by strong coal and poor availability of the French nuclear fleet. Power production across France is up by 90% year-on-year in July. Breaking this down by gas grid, we are seeing a 60% rise in PEG-Nord power plant production and an amazing 340% rise in PEG-TRS production. This is particularly amazing given that southern French gas prices have been trading 7% higher, or €1.07/MWh, than their northern neighbors.
The information above is part of PIRA Energy Group's weekly Energy Market Recap - which alerts readers to PIRA’s current analysis of energy markets around the world as well as the key economic and political factors driving those markets.
As battle lines were drawn during Libya’s long civil war, Libya’s National Oil Company (NOC) was split between East and West, with opposing governments in Tripoli and Torbruk competing over oil revenues. Libya holds Africa’s largest proven reserves of crude, however, ongoing conflict has seriously disrupted oil production and exports – Libya currently produces just 350,000 barrels per day (b/d), significantly below the 1.65 million b/d produced prior to the unrest.
With oil revenues a key source of income, attacks on oil installations have been frequent by rival groups vying for power. A statement on July 2nd – announcing the reunification of the NOC – could indicate that recovery in the Libyan oil sector is on the horizon. An NOC spokesman, Mohamed Elharari, stated that reopening the blockaded export terminals at Es Sider, Ras Lanuf, Zawiya and Zueitina was a top priority for the company. The four ports have a total export capacity of 860,000 b/d, and would significantly boost global crude supplies. Any improvement to the situation could have a substantial impact on global markets – the opening of these terminals would likely lead to downward pressure on oil prices.
However, years of war have ravaged Libya’s oil infrastructure, the lack of maintenance represents a significant barrier to increased production in the near term. Both Es Sider and Ras Lanuf have been the focus of attacks, with Ras Lanuf’s storage tanks particularly badly damaged. Key to restarting exports will be Ibrahim Jathran, head of the Petroleum Facilities Guard (PFG) – who have been blockading Libya’s export terminals since 2013. Initially set up as a politically neutral force to protect Libya’s oil facilities during the civil war, the group have arguably acted as a private militia under Jathran’s leadership. A deal between Jathran and the Tripoli-based government on the 25th July was condemned by the chairman of the NOC, Mustafa Sanalla, who stated that the deal set a “terrible precedent” for further extortion by armed groups controlling oil facilities.
As the disagreements continue, it is clear without the support of the NOC, the prospect of ports reopening remains unlikely. The reunification of Libya’s NOC is certainly a positive step for recovery, however, tremendous barriers remain – in the short to medium term, oil is unlikely to flow at the levels seen in the days of Gaddafi.
Joel Hancock, Douglas-Westwood London
As battle lines were drawn during Libya’s long civil war, Libya’s National Oil Company (NOC) was split between East and West, with opposing governments in Tripoli and Torbruk competing over oil revenues. Libya holds Africa’s largest proven reserves of crude, however, ongoing conflict has seriously disrupted oil production and exports – Libya currently produces just 350,000 barrels per day (b/d), significantly below the 1.65 million b/d produced prior to the unrest.
With oil revenues a key source of income, attacks on oil installations have been frequent by rival groups vying for power. A statement on July 2nd – announcing the reunification of the NOC – could indicate that recovery in the Libyan oil sector is on the horizon. An NOC spokesman, Mohamed Elharari, stated that reopening the blockaded export terminals at Es Sider, Ras Lanuf, Zawiya and Zueitina was a top priority for the company. The four ports have a total export capacity of 860,000 b/d, and would significantly boost global crude supplies. Any improvement to the situation could have a substantial impact on global markets – the opening of these terminals would likely lead to downward pressure on oil prices.
However, years of war have ravaged Libya’s oil infrastructure, the lack of maintenance represents a significant barrier to increased production in the near term. Both Es Sider and Ras Lanuf have been the focus of attacks, with Ras Lanuf’s storage tanks particularly badly damaged. Key to restarting exports will be Ibrahim Jathran, head of the Petroleum Facilities Guard (PFG) – who have been blockading Libya’s export terminals since 2013. Initially set up as a politically neutral force to protect Libya’s oil facilities during the civil war, the group have arguably acted as a private militia under Jathran’s leadership. A deal between Jathran and the Tripoli-based government on the 25th July was condemned by the chairman of the NOC, Mustafa Sanalla, who stated that the deal set a “terrible precedent” for further extortion by armed groups controlling oil facilities.
As the disagreements continue, it is clear without the support of the NOC, the prospect of ports reopening remains unlikely. The reunification of Libya’s NOC is certainly a positive step for recovery, however, tremendous barriers remain – in the short to medium term, oil is unlikely to flow at the levels seen in the days of Gaddafi.
Joel Hancock, Douglas-Westwood London
Exxon Mobil Corporation (NYSE: XOM) and InterOil Corporation (NYSE: IOC, POMSoX: IOC) announced an agreed transaction worth more than $2.5 billion, under which ExxonMobil will acquire all of the outstanding shares of InterOil (the ExxonMobil Transaction). “This agreement will enable ExxonMobil to create value for the shareholders of both companies and the people of Papua New Guinea,” said Rex W. Tillerson, chairman and chief executive officer of Exxon Mobil Corporation.
“InterOil’s resources will enhance ExxonMobil’s already successful business in Papua New Guinea and bolster the company’s strong position in liquefied natural gas.”
InterOil Chairman Chris Finlayson said, “Our board of directors thoroughly reviewed the ExxonMobil transaction and concluded that it delivers superior value to InterOil shareholders. They will also benefit from their interest in ExxonMobil’s diverse asset base and dividend stream.” Under the terms of the agreement with ExxonMobil, InterOil shareholders will receive:
When concluded, this transaction will give ExxonMobil access to InterOil’s resource base, which includes interests in six licenses in Papua New Guinea covering about four million acres, including PRL 15. The Elk-Antelope field in PRL 15 is the anchor field for the proposed Papua LNG project.
ExxonMobil’s more than 40 years of experience in the global LNG business enables it to efficiently link complex elements such as resource development, pipelines, liquefaction plants, shipping and regasification terminals, which it has demonstrated through the PNG LNG project, working closely with co-venturers, national, provincial and local governments, and local communities. ExxonMobil will bring to bear its industry-leading performance and strong commitment to excellence as it grows its business in Papua New Guinea.
The PNG LNG project, the first of its kind in the country, was developed by ExxonMobil in challenging conditions on budget and ahead of schedule and is now exceeding production design capacity, demonstrating the company’s leadership in project management and operations. ExxonMobil will work with co-venturers and the government to evaluate processing of gas from the Elk-Antelope field by expanding the PNG LNG project. This would take advantage of synergies offered by expansion of an existing project to realize time and cost reductions that would benefit the PNG Treasury, the government’s holding in Oil Search, other shareholders and landowners.
The ExxonMobil Transaction has been unanimously approved by the boards of both companies. The InterOil board unanimously recommends that InterOil shareholders approve the ExxonMobil Transaction.
The ExxonMobil Transaction will be implemented by way of a court-approved plan of arrangement under the Business Corporations Act (Yukon) and will require the approval of at least 66 2/3 percent of the votes cast by InterOil shareholders at a special meeting expected to take place in September, 2016.
In addition to InterOil shareholder and court approvals, the ExxonMobil Transaction is also subject to other customary conditions. Subject to obtaining the aforementioned approvals and satisfaction of closing conditions, the ExxonMobil Transaction is expected to close in September, 2016.
Further information regarding the transaction with ExxonMobil will be included in an information circular, which will be mailed to InterOil shareholders in due course. Copies of the key transaction documents for the ExxonMobil Transaction (being the arrangement agreement and the information circular) will be available online under InterOil’s corporate profile at www.sedar.com.
The InterOil board of directors, in consultation with its independent legal and financial advisors, determined that the ExxonMobil Transaction is superior to the previously announced transaction with Oil Search Limited (ASX:OSH, POMSoX: OSH) and so advised Oil Search on July 18, 2016. Immediately prior to entering into the arrangement agreement with ExxonMobil, InterOil terminated its previously announced arrangement agreement with Oil Search, and ExxonMobil is paying Oil Search the termination fee in accordance with the requirements of the Oil Search arrangement agreement on behalf of InterOil. The previously scheduled Special Meeting of Shareholders to vote for the approval of the Oil Search transaction has been cancelled.
Davis Polk & Wardwell LLP and Blake, Cassels & Graydon LLP served as legal advisers to ExxonMobil in relation to the ExxonMobil Transaction.
Credit Suisse (Australia) Limited, Morgan Stanley & Co. LLC and UBS served as financial advisers to InterOil in relation to the ExxonMobil Transaction, and Wachtell, Lipton, Rosen & Katz and Goodmans served as its legal advisers. Morgan Stanley & Co. LLC provided the InterOil board with a Fairness Opinion.
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