Mark Latham Commodity Equity Intelligence Service

Thursday 4th May 2017
Background Stories on www.commodityintelligence.com

News and Views:

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    Macro

    Chinese Commodities Crash Limit-Down As Wealth Management Product Issuance Collapses

    Chinese Commodities Crash Limit-Down As Wealth Management Product Issuance Collapses

    It seems Kyle Bass' warning was extremely timely. The deleveraging of China's $4 trillion shadow banking system just accelerated massively as Bank Wealth Product Issuance crashes 15% month-over-month. With stocks and bonds already plunging, commodities joined the ugliness tonight with Dalian Iron Ore limit down (8%) at the open (not helped by tumbling auto demand).

    As Bloomberg reports, China April Bank Wealth Product Issuance Falls 15% M/m

    Number of wealth management products issued by banks fell to 10,038 from 11,823 in March, 21st Century Business Herald reports, citing citing Wind Info data. The decline came after regulator tightens regulation on macro-prudential assessment and interbank business. Among top ten banks by wealth product sales, nine sold less than previous month (with the Agricultural Bank coillapsing 48%) only Minsheng Bank issued more.

    And it's weighing on the economy al;ready as China PMIs are all plunging (with Caixin Services tonight) - Activity in China’s services sector grew at its weakest rate in 11 months, a survey sponsored by Caixin showed on Thursday, in a further sign the world’s second-largest economy is losing some steam. The Caixin China General Services Business Activity Index fell for the fourth straight month to 51.5 in April, down from 52.2 in March and the lowest since May 2016’s 51.2, according to the poll compiled by international information and data analytics provider IHS Markit.

    As Bass concluded so ominously:

    "What you see when the liquidity dries up is people start going down... and this is the beginning of the Chinese credit crisis."

    http://www.zerohedge.com/news/2017-05-03/chinese-commodities-crash-limit-down-wealth-management-product-issuance-collapses
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    Oil and Gas

    Iraq's fuel oil exports soar despite OPEC supply cut


    Iraqi fuel oil exports have soared since January despite a reduction in the country's crude production in line with OPEC supply cuts, industry sources said, in what could be a way to boost output of refined products and maintain oil revenues.

    Iraq on average exported between 80,000 and 160,000 tonnes of fuel oil per month in 2016, data collected by Thomson Reuters Oil Research showed.

    But volumes sold to Asia have jumped this year, with Iraq's global exports of fuel oil reaching more than 500,000 tonnes in March alone, according to Reuters data.

    The soaring exports of high-quality straight-run fuel oil (SRFO) are an attempt to support revenues amid the OPEC cuts in which Iraq reluctantly agreed to participate, saying it would reduce crude output by 210,000 barrels per day (bpd).

    Iraq has processed more crude through its refineries, turning it into fuel oil for export, five industry sources with knowledge of the matter said.

    "The Iraqis have been processing more crude internally than exporting it, hence there are more fuel oil exports," said one Middle East-based industry source, speaking on condition of anonymity as he was not authorized to talk to the media.

    A manager at an Iraqi-headquartered energy trading company said: "The Iraqis have been working on optimizing fuel oil exports ... in a move to compensate for the OPEC (crude) cuts."

    Other Middle East trade sources said Iraq had been blending the high-quality fuel oil it produces with either crude or naphtha before exporting it.

    The effect has been felt as far as Singapore, Asia's main oil-trading and storage hub. Trade data compiled by Reuters shows imports of Iraqi fuel oil at 0.94 million tonnes in the first quarter of 2017, nearly double the 0.48 million tonnes imported during the whole of 2016.

    One characteristic of high-quality fuel oil is that it can be used as crude which, according to traders, is what is happening with Iraq’s supplies.

    "This stuff (the fuel oil), it's going straight into refineries," said one Singapore-based fuel oil trader, adding that Shell's 500,000-bpd Pulau Bukom refinery in Singapore had taken several cargoes of Iraqi fuel oil.

    The fuel oil, like crude, is then refined into other products such as jet fuel, gasoline or diesel. Shell declined to comment on the details of its commercial agreements.

    Traders said some of the high-grade fuel oil had also been shipped to the United States.

    Fuel oil is a byproduct of crude oil refining. High-quality variants such as SRFO can be further refined into higher-value gasoline and diesel, while lower-quality fuel oils are typically used in large marine vessels and power plants.

    Iraq's bulging fuel oil exports have contributed to a glut. In Singapore, premiums on fuel oil prices came under pressure in the first quarter as inventories hit a near eight-month high. Likewise, fuel oil inventories in the Amsterdam-Rotterdam-Antwerp hub soared to their highest since records began in 1995 in the first quarter, as fewer shipments were sent to Singapore's already burgeoning storage tanks.

    http://www.reuters.com/article/us-iraq-opec-fueloil-idUSKBN17Z0RR
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    Russia says its oil cut exceeds level demanded in OPEC-led pact



    Russia's oil production on May 1 was 300,790 barrels per day (bpd) below the level in October, meaning it has cut output by more than was demanded under a pact between OPEC and other producers, Russia's Energy Ministry said on Wednesday.

    The Organization of the Petroleum Exporting Countries, along with Russia and other non-OPEC producers, pledged to cut output by 1.8 million bpd in the first half of 2017.

    Under the deal, Russia pledged to reduce its average daily production gradually by 300,000 barrels to 10.947 million bpd from the October level of 11.247 million bpd.

    With global crude inventories still bulging, investors are now focussed on whether OPEC and others will agree to extend the cuts to the second half of the year. The issue will be discussed by the group of producers at an OPEC meeting on May 25.

    Russian Energy Minister Alexander Novak has said he would meet managers of key Russian oil producer before the OPEC event to discuss extending the cuts. Industry sources say such a meeting has yet to take place.

    Novak declined say on Friday on whether Russia would support an extension to the pact. Russia's Deputy Prime Minister Arkady Dvorkovich also declined to comment when asked on Wednesday

    http://www.reuters.com/article/us-oil-opec-russia-cuts-idUSKBN17Z11R
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    Nigeria pays initial $400 mil owed foreign oil partners, eyes 2.5 mil b/d output by 2019


    Nigeria has made an initial payment of $400 million, out of the $5.1 billion debt owed to its foreign oil partners, as it kickstarted a new funding mechanism for upstream ventures aimed at boosting investment in the oil and gas sector, oil minister Emmanuel Kachikwu said Wednesday.

    In December 2016, the government signed a new funding arrangement with Shell, ExxonMobil, Chevron, Total and Eni, that would see Nigeria exit the system of contributing money to fund its average 57% equity in the ventures, known locally as cash call, and allow producers to independently source funds and control their own budgets.

    "The first payment of $400 million was paid last week to the IOCs [International Oil Companies]. The $400 million payment was part of cash call debt owed the IOCs in 2016," a statement Wednesday from the oil ministry quoted Kachikwu saying.

    "The sustainable funding of the [joint ventures] will lead to an increase in national production from the current 2.2 million b/d to 2.5 million b/d by 2019," the minister said.

    Nigerian oil production still remains sharply below its capacity of 2.2 million b/d, with the main export grade Forcados still shut in.

    Output has recovered gradually this year as militant attacks have fallen substantially since early January after the government stepped up peace talks in the key producing Niger Delta to end militancy in the region.

    Nigerian crude oil and condensate production is currently around 1.9 million b/d, with almost 350,000 b/d comprising condensates like Akpo, Agbami and Oso Condensate, according to S&P Global Platts estimates.

    Nigeria is currently exempt from the OPEC production cuts because of the issues it is facing with militancy in the Niger Delta.

    The six-month deal, which expires in June, will be up for review at OPEC's next meeting on May 25, with some ministers saying the production cuts should be extended to continue drawing down global inventories.

    Sources have said that with Nigeria restoring output, it could be asked to join the output cuts, if the deal is extended.

    In late November oil minister Emmanuel Kachikwu acknowledged that a fully recovered Nigeria would likely be asked to share in the cuts.

    On the debt to IOCs, Nigeria owed $6.8 billion as at September 2016, under the previous funding mechanism.

    Kachikwu said that in exiting the cash call arrangement, Nigeria secured 25% or $1.7 billion discount on this debt following the agreement reached with the companies.

    "The immediate effect of the new cash call policy will increase net Federal Government revenue per annum by about $2 billion," the minister said.

    Apart from the disruption in the Niger Delta, the lack of proper funding had stunted the growth of Nigeria's oil production and state oil firm NNPC said late last year that joint venture production dropped to about 800,000 b/d now from 1.2 million b/d six years ago following the government's inability to properly fund the joint ventures.

    Kachikwu also said the Nigerian government was in talks with foreign companies for the latter to take more responsibility for infrastructure security in the Niger Delta in a bid to end militancy in the region.

    https://www.platts.com/latest-news/oil/lagos/nigeria-pays-initial-400-mil-owed-foreign-oil-26726303
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    Shell’s 1Q profit soars


    Royal Dutch Shell has reported a sharp rise in its first quarter profit, boosted by chemicals and upstream segment of its business.

    Current Cost of Supplies (CCS) Income excluding identified items was $3,86 billion, up from $1,6 billion a year ago.

    The $2.2 billion increase from the first quarter of 2016 was mainly driven by higher contributions from Upstream and Chemicals, partly offset by higher net interest expense, Shell said.

    Royal Dutch Shell Chief Executive Officer Ben van Beurden said: “The first quarter 2017 was a strong quarter for Shell. Cash flow from operating activities of $9.5 billion and free cash flow of $5.2 billion enabled us to reduce debt, and cover our cash dividend for the third consecutive quarter. We saw notable improvements in Upstream and Chemicals, which benefited from improved operational performance and better market conditions. Our operations in Qatar are restarting during the second quarter.

    “We continue to reshape Shell’s portfolio and to transform the company with over $20 billion divestments completed or announced that will strengthen the balance sheet as they are completed.”

    “The strategy we have outlined to deliver a world-class investment case is taking shape. Following the successful integration of BG, we are rapidly transforming Shell through the consistent and disciplined execution of our strategy. This includes investing around $25 billion this year and the delivery of new projects, which we expect to generate $10 billion in cash flow from operating activities by 2018.”

    Upstream

    On the Upstream side, During the quarter, Shell made a final investment decision (“FID”) for the Kaikias deep-water project in the Gulf of Mexico.  Shell announced the sale of a package of United Kingdom North Sea assets, oil sands and in-situ interests in Canada, and onshore interests in Gabon.

    Upstream earnings excluding identified items were $540 million, compared to a loss of $1.4 billion a year ago.

    Compared with the first quarter 2016, Upstream earnings excluding identified items benefited from higher realised oil and gas prices, increased production volumes mainly from new assets and improved operational performance, and lower depreciation including the impact of assets held for sale.

    Compared with the same quarter a year ago, cash flow from operating activities increased as a result of higher prices and volumes. The production contribution of BG assets for an additional month, compared with the first quarter 2016, was some 211 thousand boe/d.

    New field start-ups and the continuing ramp-up of existing fields, in particular Lula Central, Lula Alto and Lapa in Brazil, Kashagan in Kazakhstan, Sabah Gas Kebabangan in Malaysia, and Stones in the Gulf of Mexico, contributed some 142 thousand boe/d to production compared with the first quarter 2016, which more than offset the impact of field declines, Shell said.

    Looking ahead, Shell said that compared with the second quarter 2016, Upstream earnings are expected to be negatively impacted by a reduction of some 45 thousand boe/d associated with completed divestments, and by some 50 thousand boe/d associated with the impact of lower production at NAM in the Netherlands. Earnings are expected to be positively impacted by some 55 thousand boe/d associated with lower levels of maintenance.

    http://www.offshoreenergytoday.com/shells-1q-profit-soars/
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    Statoil Q1 results significantly better than expected


    Norway's Statoil ASA posted a forecast-beating first-quarter net profit Thursday, driven by higher oil prices and increased production while making good progress on its cost-efficiency drive.

    Production from the Norwegian continental shelf was at its highest level in five years, and its international portfolio delivered positive results and cash flow per barrel after tax on par with its Norwegian portfolio, it said.

    The 67% state-owned company confirmed it would deliver a further $1 billion in annual cost savings this year, backing a target it outlined in February and bringing savings this year to $4.2 billion.

    Capital expenditure in 2017 is expected to remain at the 2016 level of around $11 billion, while exploration expenses are still seen at around $1.5 billion, excluding signature bonuses.

    Statoil still expects 4%-5% production growth in 2017 and organic annual production growth of around 3% from 2016 to 2020.

    Net profit for the three months through Mar. 31 was $1.06 billion, compared with $611 million a year earlier. Analysts had expected a net profit of $739 million. Revenue rose 53% on the year to $15.47 billion, against expectations of $14.61 billion.

    The company maintained its quarterly dividend at $0.2201 a share.

    Statoil's adjusted earnings before interest and taxes, which excludes one-off items to show the company's underlying performance, rose to $3.31 billion, against analysts' expectations of $2.64 billion. Higher prices for oil and North American gas, solid operational performance with high production and continued progress on improvement initiatives contributed to the increase, it said.

    http://www.marketwatch.com/story/statoil-earnings-beat-expectations-2017-05-04
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    Lundin ups output guidance, brushes off Arctic setback


    Sweden's Lundin Petroleum lifted its full year production guidance on Wednesday and said it still expected to find more oil in the Barents Sea despite a recent setback.

    Lundin, a partner in Norway's giant Johan Sverdrup field, reported $355.8 million in earnings before interest, tax, depreciation and amortisation (EBITDA), above the forecast of $325 million in a Reuters survey of analysts.

    Lundin said it was able to increase production capacity at its Edvard Grieg platform to 145,000 barrels of oil equivalents per day (boepd) from its designed capacity of 126,000.

    "This outstanding performance has led us to revise Lundin Petroleum's full year production guidance to between 75,000 and 85,000 boepd, and to reduce our cash operating cost guidance for the full year to $4.90 per barrel," it said in a statement.

    The previous guidance was 70,000-80,000 boepd and $5.30 per barrel respectively, excluding output from Lundin's assets outside Norway that were spun off to International Petroleum Corporation (IPC) in April.

    A recent appraisal well at Edvard Grieg's southwestern flank confirmed the resource upside of gross 10–30 million boe.

    Lundin's Chief Executive Alex Schneiter said it was "fair to assume" that Edvard Grieg plateau production would be extended beyond the original two-year period due to better reservoir performance.

    Lundin has a 65 percent stake in the Edvard Grieg field, Austria's OMV 20 percent and Germany's Wintershall , a unit of chemicals giant BASF, 15 percent.

    ARCTIC SETBACK

    Separately, Lundin said it would have to reduce its previous resource estimate of between 91 million and 184 million boe at the Gohta prospect in the Barents Sea after the latest appraisal well turned out to be dry.

    The setback, however, would not jeopardise the development of the nearby Alta find, estimated to contain 125-400 million boe, added the firm.

    "Clearly there will be a reduction on Gohta, but Alta is the main discovery where we have been focusing the development (plans)," Schneiter said.

    Lundin plans to drill an appraisal well at its Alta prospect later this year, and Schneiter confirmed on Wednesday plans to drill two more exploration wells near the Filicudi 35-100 million boe discovery made in February.

    It is also a partner in the Korpfjell prospect in the Barents Sea near the border with Russia, which Statoil plans to drill this summer.

    http://www.reuters.com/article/lundinpetroleum-norway-idUSL8N1I51GB
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    CNPC loads first crude oil into Myanmar-China pipeline


    China's state-owned refiner China National Petroleum Corp (CNPC) said it has loaded the first crude oil through its Myanmar-to-China pipeline, the latest step towards supplying crude to its new refinery in Yunnan province.

    Some 1,150 cubic meters per hour of crude flowed into the 770-kilometre (480 mile) pipeline from Tuesday, CNPC said in a statement on Tuesday.

    The move comes almost a month after the first tanker carrying 140,000 tonnes of crude started discharging into the pipeline following the official launch.

    CNPC's PetroChina plans to import overseas oil and pump it through the pipeline to supply its new 260,000-barrels-per-day Anning refinery in landlocked Yunnan province.

    The pipeline starts at Kyauk Phyu in Myanmar's west and enters China at the border city Ruili and is a joint investment by CNPC and the Myanmar Oil and Gas Enterprise.

    http://www.reuters.com/article/china-myanmar-oil-idUSL1N1I504H
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    Bassoe: Use ’em while they’re hot. Oil companies should contract more offshore rigs now instead of later


    Oil companies have shunned the offshore industry for the past three years as breakeven costs for new projects haven’t been in line with oil prices. Now oil prices have stabilized, and the consensus is that prices will stay in a $50–70/barrel range for the medium-term.

    At the same time, costs have come down considerably for drilling and services, and oil companies have implemented efficiency programs which allow them to reduce breakeven costs for new projects. Projected costs out to 2020 show that virtually all projects onshore and offshore can tolerate oil prices in the forecasted price band.

    One would think that oil companies would start sanctioning new drilling projects in all segments. But they’re not – at least not on a large enough scale to ensure that global depletion rates don’t reach unsustainable levels. Instead, the current trend is on “short-cycle” onshore projects with high decline rates and on optimizing current production.

    Offshore projects normally offer larger production volumes, but they have higher cost and time requirements. So many offshore projects have been cancelled or put on hold over the past few years that the number of new wells drilled has reached its lowest point ever.

    New, large scale offshore development is needed to maintain oil production at levels that will avert a sudden supply deficit (and a subsequent dramatic increase in oil prices). Oil companies have heard this, and pretty much everyone else has too. But little is being done about it.

    During the past ten years, oil companies spent so much on offshore drilling that field development costs became unsustainable as the oil price started to fall. The price fall didn’t happen fast enough, however, to restrain the expectations of continued high activity in the rig market which led to too many rigs being built.

    When oil prices crashed and everything suddenly stopped, oil companies were left incapacitated, financially constrained, and unable to take on new projects.

    But now that oil companies can operate in a lower cost offshore environment due to high rig supply and better efficiency, they would be better off initiating new projects now instead of later. Although the resulting increase in the oil price from a supply crunch could partially and temporarily offset any of the higher costs oil companies would incur in field development (due to higher rig demand, for example), betting on the extent and longevity of this is risky.

    More importantly, however, continued low activity threatens the viability of their drilling asset base.

    Oil companies risk instability, project delays, and higher costs for offshore projects

    As every day goes by, the negative effects of rig stacking (i.e., longer time to get rigs back into the market, higher risk of operational issues, and higher costs) multiply.

    While tendering activity for offshore rigs is finally increasing, it’s not happening fast enough. Procrastination by oil companies along with their lack of agility and limited offshore focus have driven rig owners into damage control mode. Rig owners have had to implement massive job cuts, defer newbuild deliveries, and stack rigs with up to hundreds of millions of dollars of systems and equipment onboard.

    Extended low (or slowly increasing) drilling activity risks being outpaced by the decreasing number of optimal rigs (i.e., operational, warm stacked, or well-preserved) which are available to oil companies. As we mentioned last week, for established rig owners who implement proper stacking for their rigs, rig oversupply isn’t a major issue – this situation will be great for them. But for oil companies, the consequence of prolonged aversion to sanctioning offshore projects is potentially compromised operations (because, eventually, oil companies will be forced to take “worse” rigs as the supply of optimal rigs decreases).

    Compounding the growing supply of deteriorating rigs is the fact that rig owners are losing skilled personnel. When rigs need to be put back in service and operated, there will be a lack of competence and consistency in the industry.

    Oil companies have kicked the can down the road. When they reach that can again, however, they will find it battered, rusty, and emptier than it was before. And they’ll still need to use it.

    The oversupplied offshore rig market offers oil companies a perfect opportunity. They can find high quality rigs in nearly all offshore regions at dayrates not seen before. Compared to $600,000 per day for a UDW drillship or $180,000 per day for a high spec jackup, they can contract these rigs for less than 50% of those costs now.

    Oil companies should be sanctioning offshore projects faster and taking advantage of a scenario they haven’t seen in decades: low dayrates and high supply of new rig assets. By moving early, they will ensure that they will be able to accommodate the expected need for new offshore wells, keep costs low, and help maintain the rig fleet.

    http://www.offshoreenergytoday.com/bassoe-use-em-while-theyre-hot-oil-companies-should-contract-more-offshore-rigs-now-instead-of-later/

    Attached Files
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    Woodside resumes LNG production at Karratha gas plant


    Australian LNG player Woodside said liquefied natural gas production resumed at the Karratha gas plant following an outage on April 15.

    The Karratha gas plant is located some 1260 kilometers north of Perth, Western Australia, and is a part of the North West Shelf project facilities.

    “Domestic gas production was restored at the Karratha gas plant on 18 April following an unplanned outage that occurred on 15 April,” North West Shelf project’s spokesperson said.

    In its emailed response, the spokesperson added the underlying cause of the incident was an electrical fault.

    “We have now recommenced full liquefied natural gas (LNG) production,” the spokesperson said.

    The Karratha gas plant facilities include five LNG processing trains, two domestic gas trains, six condensate stabilisation units, three LPG fractionation units as well as storage and loading facilities.

    It has an annual LNG export capacity of 16.9 mtpa which is supplied mainly to companies in the Asia Pacific region.

    Woodside operates these facilities on behalf of the NWS project participants. Other NWS JV partners are BHP Billiton, BP, Chevron, Japan Australia LNG (MIMI) and Shell.

    http://www.lngworldnews.com/woodside-resumes-lng-production-at-karratha-gas-plant/
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    European May styrene premium over feedstocks tumbles to four-year low


    European styrene's premium over feedstocks has tumbled to a four-year low in May as the styrene contract price fell Eur245/mt or 18% over the month, while feedstock costs were largely steady, according to S&P Global Platts data.

    The May styrene contract price was fully settled at Eur1,130/mt ($1,233/mt), down Eur245/mt over the month.

    Despite the sharp fall in styrene, feedstock costs were largely flat.

    The May ethylene contract price was agreed at Eur1,150/mt, unchanged on the month, while the benzene contract price was settled at Eur754/mt, up Eur9/mt.

    Using a formula of 0.29 ethylene to 0.79 benzene to calculate feedstock costs, May costs are estimated at Eur900/mt, up Eur7/mt over the month.

    However, the sharp decrease in the styrene contract level meant that styrene's premium over feedstocks dropped to Eur230/mt. It is also the lowest level since May 2013, according to Platts data.

    "It is the lowest spread [over costs] in four years," a styrene buyer said.

    This is a reversal in fortunes from earlier in the year when the styrene premium over feedstocks was calculated at Eur605/mt, a multi-year high.

    Through April, movement in styrene spot diverged significantly from benzene and ethylene, leading to a large drop in styrene's premium over costs.

    https://www.platts.com/latest-news/petrochemicals/london/european-may-styrene-premium-over-feedstocks-26725023
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    US lower 48 oil production up 25,000 bbls day


                                              Last Week   Week Before    Last Year

    Domestic Production........... 9,293            9,265           8,825
    Alaska ....................................... 526                523              430
    Lower 48 .............................. 8,767             8,742           8,395

    http://ir.eia.gov/wpsr/overview.pdf
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    Summary of Weekly Petroleum Data for the Week Ending April 28, 2017


    U.S. crude oil refinery inputs averaged about 17.2 million barrels per day during the week ending April 28, 2017, 108,000 barrels per day less than the previous week’s average. Refineries operated at 93.3% of their operable capacity last week. Gasoline production increased last week, averaging 9.8 million barrels per day. Distillate fuel production increased last week, averaging 5.1 million barrels per day.

    U.S. crude oil imports averaged about 8.3 million barrels per day last week, down by 648,000 barrels per day from the previous week. Over the last four weeks, crude oil imports averaged over 8.2 million barrels per day, 4.9% above the same four-week period last year. Total motor gasoline imports (including both finished gasoline and gasoline blending components) last week averaged 693,000 barrels per day. Distillate fuel imports averaged 112,000 barrels per day last week.

    U.S. commercial crude oil inventories (excluding those in the Strategic Petroleum Reserve) decreased by 0.9 million barrels from the previous week. At 527.8 million barrels, U.S. crude oil inventories are near the upper limit of the average range for this time of year. Total motor gasoline inventories increased by 0.2 million barrels last week, and are near the upper limit of the average range. Finished gasoline inventories decreased while blending components inventories increased last week. Distillate fuel inventories decreased by 0.6 million barrels last week but are in the upper half of the average range for this time of year. Propane/propylene inventories increased slightly but remained virtually unchanged from last week and are in the lower half of the average range. Total commercial petroleum inventories increased by 1.3 million barrels last week.

    Total products supplied over the last four-week period averaged 19.6 million barrels per day, down by 2.4% from the same period last year. Over the last four weeks, motor gasoline product supplied averaged over 9.2 million barrels per day, down by 2.7% from the same period last year. Distillate fuel product supplied averaged 4.2 million barrels per day over the last four weeks, up by 3.3% from the same period last year. Jet fuel product supplied is down 0.1% compared to the same four-week period last year.

    Cushing down 700,000 bbls

    http://ir.eia.gov/wpsr/wpsrsummary.pdf
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    BP: Deep water can compete with shale 'any day'


    BP's efforts to cut costs in the deep-water Gulf of Mexico have led to higher operating margins than before the downturn making the prolific producing region now far more competitive with shale, a company official said.

    "Today our cash margins in the Gulf of Mexico are better than they were when the price of oil was $80 a barrel," said Richard Morrison, BP's regional president of the Gulf of Mexico, speaking at the Offshore Technology Conference in Houston on Monday.

    The UK supermajor is one of the biggest oil producers in the US Gulf and operates four major production hubs as well as multiple deep-water drilling units.

    Since 2014, however, BP has paused its exploration programme in the region and "refocused" its portfolio. It has "halved" its fleet of vessels and helicopters in the region and nearly halved its onshore Gulf of Mexico workforce, Morrison said.

    Meanwhile, some of BP's top competitors in the deep-water US Gulf like ConocoPhillips and Marathon Oil have directed more and more spending on US shale and tight oil, where economics are said to be better.

    With the changes BP has made to its deep-water business, Morrison said the US Gulf now "can compete with tight onshore oil any day - any day."

    Optimising the portfolio, spreading out risk through operated and non-operated stakes and improving overhead and lifting costs were all vital to improving the economics, he said.

    These days deep-water breakeven costs for BP are below $40 a barrel compared to $80 in 2014.

    "The economics for deep-water investments make as much sense today as they did back in 2001. Back then, the oil price was hovering around $20 a barrel and material discoveries were being made,” Morrison said.

    That was the same year BP’s giant Thunder Horse development project was sanctioned, tapping one of the biggest discoveries to date in the Gulf of Mexico.

    Tiebacks are leading the way as players reinvent US Gulf projects

    Subsea tiebacks to existing infrastructure have also made investment decisions easier thanks to reduced cycle times and more reliance on industry standards.

    Morrison described a “new mindset” at BP regarding tiebacks.

    "Tiebacks are no longer an interesting side business. They are integral to both the midterm and longer term plans in deep-water,” he said.

    BP's approach to development is becoming “more standardised and supplier-led", he said.

    "We were getting into a place where perfection and design-tweaking had gotten in the way of good business," he said.

    BP is now using its engineering expertise is to minimise risk "rather than designing the pristine solution".

    This has led to shorter development cycle times. For subsea tiebacks, BP expects between 10 and 20 months from sanction to first oil, versus a typical 36 to 48 months previously.

    "We have modified our approach by looking to industry to supply us their standard products and solutions rather than imposing BP standard on the supply chain," Morrison said.

    http://www.upstreamonline.com/live/1250813/bp-deep-water-can-compete-with-shale-any-day
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    Slumping oilfield services sector bets on new offshore technology


    The oil industry's top equipment and services suppliers this week are hawking vastly cheaper ways of designing and equipping subsea wells, aiming to slash the cost of offshore projects to compete with the faster-moving shale industry.

    At the Offshore Technology Conference, the industry's annual gathering of floating rig and subsea well suppliers, sales pitches this year are all about cost savings and faster time to first production. With U.S. crude priced CLc1 under $50 a barrel, offshore projects with their typically high costs and long-lead times are now borrowing from leaner shale in the competition for oil company investment.

    Low oil prices have soured new exploration in the U.S. Gulf of Mexico, for instance, but production volumes there have remained strong due to the long lead times of these projects. Gulf of Mexico producers are expected to add 190,000 barrels per day this year to output now running about 1.76 million bpd.

    Tool and services companies are offering new technologies that can do several jobs, taking the place of multiple devices or highly-paid consultants.

    National Oilwell Varco Inc (NOV.N) is exhibiting software it touts as performing much like a drilling expert, sorting through vast amounts of data to find ways to speed production and reduce downtime.

    The new software "takes actions a person would do and runs them automatically. It's low cost and it's simple" said David Reid, National Oilwell Varco's chief marketing officer.

    Baker Hughes Inc (BHI.N) is showing a new tool called DeepFrac that it said eliminates several steps now required to complete underwater wells. That saving pares the price of a well by up to 40 percent, speeding first production and lowering the break-even cost for producers.

    "This helps sharply cut some of the risk of drilling an offshore oil well and, we believe, sharply reduces costs for our customers," said Jim Sessions, a vice president of technology at Baker Hughes.

    Graham Hill, an executive vice president at KBR Inc (KBR.N), detailed the construction company's plan for a cheaper floating production vessel, saying the new vessel fits producers' tight budgets. KBR can hope to earn more by selling extra features.

    "This is like ordering a Ford," he said. "There's a base package, and you can add extras."

    Richard Morrison, president of BP plc (BP.L)'s Gulf of Mexico region, said the industry has accepted that crude prices will probably stay low, meaning oil producers like BP must work with services providers to reduce the multibillion dollar cost of offshore projects.

    "That break even point can't come back to $80 a barrel, so I've got to figure out ways to work with my supplier over the long-term to keep that in check," he said during a presentation.

    Morrison touted BP's use of new seismic imaging technology that helped identify 1 billion additional barrels of "possible resources" at four of its U.S. Gulf of Mexico offshore fields. The technology enhances existing seismic images to find oil hidden beneath salt structures deep underground.

    Just weeks away is a coming Vienna meeting of the Organization of the Petroleum Exporting Countries where OPEC and other oil producers are to decide whether to continue production curbs past June.

    If OPEC fails to continue the curbs, oil prices could fall again, making a difficult market worse, said Charles Cherington, a co-founder of Intervale Capital, a private equity investor in oilfield services.

    Assuming OPEC continues the existing curbs, Cherington said the best the industry can hope for this year is crude "gets to the low to mid $50s (a barrel)" or half what it fetched at this time three years ago.

    Few oilfield suppliers are generating steady profits, he said, and "in the short run, we don't see the market getting much better," he added.

    Marc Gerard Rex Edwards, chief executive of rig provider Diamond Offshore Drilling (DO.N), on Monday reported its first quarter earnings declined on revenue down 25 percent from a year ago.

    "I think we're beginning to see the signs of a bottom," he told Wall Street analysts, adding: "But I'm not exactly calling a bottom in the market at this particular moment in time."

    http://www.reuters.com/article/us-oilservices-otc-outlook-idUSKBN1800BI

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    Eagle Ford, STACK Shine for Devon in Q1


    Devon targets 20 U.S. operated rigs by year-end

    Devon Energy Corp. (ticker: DVN) reported stronger than expected production results Tuesday as the company’s U.S. resources outperformed its earlier guidance. Oil production averaged 261 MBOPD, up 7% sequentially, 5 MBOPD more than the top end of the company’s guidance.

    The growth was driven entirely by Devon’s U.S. resource plays where the company is also seeing the highest margins in its portfolio, according to the DVN press release.

    Eagle Ford, STACK completions add up

    In total, U.S. oil production reached 123 MBOPD in the first quarter, a 17% increase from the previous quarter, thanks to higher completion activity across the company’s Eagle Ford and STACK operations. Including Eagle Ford partner activity, the company exited the first quarter with 15 rigs operating.

    Plowing $2+ billion into U.S. plays in 2017

    Devon’s full-year 2017 goals are to grow production 13% to 17%, which the company believes it can deliver by investing between $2.0 billion and $2.3 billion of E&P capital in 2017, with nearly 90% of the capital dedicated to U.S. resource plays.

    The company plans to steadily increase drilling activity throughout the year to as many as 20 operated rigs by the end of the year.

    Jackfish exceeding nameplate capacity by nearly 20%

    Further north of Devon’s U.S. assets, its heavy-oil operations in Canada averaged 138 MBOPD in the first quarter, a 9% increase year-over-year. The growth was driven by its Jackfish complex, where gross production increased to a record 125.1 MBOPD during Q1, according to the company. The record production is exceeding the facility’s nameplate capacity by nearly 20%, Devon said in its earnings release.

    Operating cash flow expands 54%

    Devon’s reported net earnings totaled $565 million or $1.07 per diluted share in the first quarter. Adjusting for items securities analysts typically exclude from their published estimates, the company’s core earnings totaled $217 million or $0.41 per diluted share in the first quarter, exceeding consensus expectations.

    The company’s profitability in the first quarter was attributable to strong production growth, higher commodity prices and an improved cost structure, DVN said in the press release. These factors also strengthened Devon’s operating cash flow to $834 million, a 54 percent increase from the fourth quarter of 2016.

    Devon reported $2.1 billion of cash on hand at the end of the quarter. The company paid off $2.5 billion of debt during the course of 2016, pushing any significant debt maturities out until mid-2021. DVN also reported that more than 50% of its estimated oil and gas production for this year is hedged, and that the company is currently working on accumulating additional hedges for 2018.

    https://www.oilandgas360.com/eagle-ford-stack-shine-devon-q1/

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    Anadarko, Bill Barrett Add Sand, Reduce Stage Spacing in DJ Basin


    Q1 production up despite low 2016 activity; Anadarko drills a long lateral in record 5.2 days

    Two major Niobrara players, Anadarko Petroleum (ticker: APC) and Bill Barrett Corporation (ticker: BBG) held conference calls today, reporting similar strategies for success in the basin.

    Anadarko reported sales of 242,000 BOEPD from its DJ basin properties, a slight increase from Q1 2016 despite reduced activity in 2016. The company added one rig this quarter, and now has six operated rigs and two completion crews active in the basin.

    Anadarko continues to drill quicker wells, reporting a new record for completing a long lateral well: 5.2 days. For reference, in Q4 2016 the company reported a record of 5.5 days to complete a long lateral in the basin.

    Like many unconventional operators in the U.S., Anadarko has been experimenting with more intense completion designs. Recent wells have been completed with increased fluid volumes and tighter stage spacing. The company reports that early results from these new wells show improvements of over 10% relative to older designs.

    Anadarko’s Advanced Analytics and Emerging Technology group is designing these improvements based on data from the company’s old wells. In today’s conference call, APC Senior VP of U.S. Onshore Exploration and Production Brad Holly commented “we’re really excited about what we’re seeing in the DJ because we have done over 1,000 wells out there. We’ve taken all that data along with everything we’ve seen in the industry and really ran it through our advanced analytics and looking at every component that makes up that fracture thing.

    “We’re working on increased fracture intensity, which is really we’re trying to bust up the rock as much as possible. We have shrunk our stage basin as well as increased our fleet volumes and we’re continuing to tweak that recipe. We did a few of those in the fourth quarter of 2016 and we started to do quite a few more of those in the first quarter of 2017.

    “So, we put some of our early results out in the ops report and we’re continuing to watch results, but we’re encouraged and excited about what we’re seeing from the new completion design. We continue to tweak that and we’ll have more information as we get more production results.

    “We’re certainly looking at more fluid, and I think we’re playing with some of the other parameters and what combinations to pump these things.”

    Bill Barrett design improvements give 45% ROR

    Bill Barrett Corporation has reported similar keys to success. Current completion designs involve increasing sand concentration and decreasing stage spacing. Based on the past two years of production history increasing sand concentration from 1,000 lbs/ft to 1,200 lbs/ft improves production by 36%. Similarly, decreasing stage spacing from 170 ft/stage to 120 ft/stage indicates 10% or greater cumulative production. Bill Barrett is combining these improvements this year, with a base design of 1,500 lbs/ft of sand and frac spacing of 100 ft/stage to 140 ft/stage. These design enhancements have improved well returns to about 45% at current prices.

    Bill Barrett President and CEO R. Scot Woodall mentioned that further improvements are possible, depending on the results of current wells. “We obviously are kind of watching what others are doing as well,” Woodall commented, “but I know a current pad that’s being completed right now is going to go to 100-foot stage spacing. So that’ll be testing one of the lower ends. And I think we’ll have to look at some results of the 1500 pounds and see if we need to go larger or not. There’s some operators that are doing some more. I think we can look at those results. So I think we’ll evolve throughout the year a little bit.”

    In total, Bill Barrett plans to drill 70 to 75 wells in the DJ basin this year. The company currently  has one active rig in the basin, but plans to add a second during Q2 2017. First quarter production from the DJ was up 22% year-over-year at 14,200 BOEPD.

    Quarterly results improving year-over-year

    Anadarko reported a net loss of $318 million, or ($0.58) per diluted share, vastly exceeding the company’s Q1 2016 loss of $1 billion. Bill Barrett reported a net loss of $13 million, ($0.18) per diluted share, up from the $46.5 million loss the company reported this time last year.

    https://www.oilandgas360.com/anadarko-bill-barrett-add-sand-reduce-stage-spacing-dj-basin/
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    Panama Canal to see daily LNG carrier transits within 4 years, says CEO


    The number of LNG carrier transiting the Panama Canal could average one a day by 2021 as more US supply comes on stream and targets demand in North Asia, according to Panama Canal Authority CEO Jorge L. Quijano.

    "During the past nine months of operation of the Panama Canal we have seen LNG flows that we never expected a few years back," Quijano said on the sidelines of the Sea Asia Conference, held in conjunction with the Singapore Maritime Week 2017 last week.

    The initial projection was for one LNG ship a week but this had already reached three to four ships, he said.

    Much of the future traffic will be driven by emerging LNG exports from the US, of which some will pass through the canal, he said.

    Cheniere has three fully operational LNG trains at Sabine Pass on the US Gulf Coast, with a fourth train undergoing commissioning expected to reach substantial completion in second half 2017, the company said in April.

    Train five is currently under construction and slated to become operational in 2019, and train six fully permitted and being commercialized, it added.

    Cheniere also has two trains under construction at its liquefaction project near Corpus Christi in Texas, with operations at both trains expected to begin in 2019, the company said.

    Other US LNG projects slated to start production in the near future include Freeport LNG, Cameron LNG in Louisiana and Cove Point LNG.

    "The prospects are really good for LNG transits for us and as you have more LNG and more fracking, there will be more LPG as well," Quijano said.

    "We previously had LPG Panamaxes going through. We have more than tripled the amount of LPG going through the Panama Canal now that we have the bigger locks and we can handle the very large gas carriers," he said, adding: "So that has also been a surprise."

    In addition to LNG cargoes to North Asia, the Pacific side of Mexico has accounted for almost 55% of the LNG passing through the canal to date.

    LPG and LNG are providing extra revenue for the Panama Canal in addition to the container trade, Quijano said.

    "The container trade is [still] important for us because that represents 50-51% of our revenue," he said.

    Container ships ranked first in both the number of canal transits and total cargo tonnage in 2016, with the dry bulk segment second. Crude and products tankers comprised 7.4% of total cargo tonnage in the year, LPG carriers 5.6% and LNG vessels 0.3%, Platts reported in March.

    The Panama Canal Tuesday had its largest vessel both in dimension and capacity transit the Expanded Canal since it was inaugurated in June 2016.

    https://www.platts.com/latest-news/natural-gas/singapore/panama-canal-to-see-daily-lng-carrier-transits-27824474

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    Alternative Energy

    Record $7.5bn Aus renewables spend puts RET well within reach


    The latest data from the Clean Energy Council and the Clean Energy Regulator confirm that Australia is experiencing its biggest ever investment spree in large scale renewable energy, and the 2020 renewable energy target, once considered impossible to meet, is now well within reach.

    The CEC on Wednesday released new figures that put the value of large scale wind and solar projects, and one solitary biomass plant, beginning construction in 2017 at $7.5 billion.

    The tally, spread evenly around the country, with the exception of Western Australia and Tasmania, represents 3,549MW, with large scale solar overtaking large scale wind, and will result in the creation of 4,105 jobs during the building phase.

    More than $2 billion worth of these renewable energy projects have attracted financial commitment in just the last three months, boosted by a string of large-scale solar project announcements since February as solar costs challenge wind energy.

    “Large-scale renewable energy, combined with the continued strong uptake of rooftop solar and emergence of energy storage, provides a clear pathway for Australia’s future energy needs,” CEC chief executive Kane Thornton said, adding that new generation was necessary to ensure energy security as coal plants such as Hazelwood retired.

    The Clean Energy Regulator also released its own data, which shows that the surge in project announcement, particularly in the more quickly-constructed solar plants, means that the 2020 target is likely to be reached – and a long predicted deficit in large scale certificates in 2018 may also be averted.

    The pace is so great that according to executive general manager Mark Williamson, enough projects could be committed by the end of this year to meet the 2020 target – that will be one year earlier than anticipated. Already, 3,300MW has been committed in the last 15 months, and most of it in the last six to eight months and there was a huge pipeline ahead.

    The main cause is the push to solar, which is falling in costs and can be built faster. The use of single axis tracking is also increasing its output from around 25 per cent capacity to more than 30 per cent capacity.

    “The momentum we saw in the second half of 2016 has continued into 2017. Already we have one-third of the total build required for 2017 achieved in the first four months of the year. If we continue like that, we will get enough commitments by the end of the year. And our market information is that there are some big announcements coming in the net few months.

    “This demonstrates that Australia is now in a strong position to meet the 2020 Renewable Energy Target,” Williamson said. To which Wayne Smith, from the Australian Solar Council retorted: “Perhaps we should go back to the original RET target of 41,000GWh.” The target was cut under the Abbott administration.

    The fact that the target will likely be met means the current high price of large scale generation (LGC) certificates will fall from their current levels above $80/MWh, a level that has attracted huge interest in the Australian market from international players. Already, it is down to around $76/MWh

    Even though the target will largely depend on the action of the major players in the market, particularly the retailers, it suggests the market is doing  its job.

    The shortage of projects was reflected in the high price, and that has provided a signal for more projects. Hence the target was met. Most project developers would have preferred a more stable policy environment, given the investment drought caused by the uncertainty of the RET under the Abbott government.

    Solar is the big focus of development, Of the 98 new power plants above 100kW that were accredited in 2016, 86 were solar, which federal energy minister Josh Frydenberg said reflects the rapidly declining cost and increased capacity of solar PV.

    Australia’s energy market is undergoing an unprecedented and unstoppable transformation,” Frydenberg wrote in an article for the Australian Financial Review.

    “What is remarkable is the how fast the cost of these new technologies are coming down.” He described this as “good news” and said the technology could be successfully integrated with the right planning.

    The CEC, meanwhile, says that there are 35 projects that are already under construction, will start construction or have been completed in 2017.

    “Large-scale solar technology has approximately halved in price over just the last few years, making it competitive not only with wind power but with fossil fuels such as gas,” Thornton said.

    “Renewable energy is now the cheapest kind of power generation it is possible to build today, and solar power plants have a relatively short project lead time compared to other technologies.

    “Regional New South Wales and Queensland in particular will enjoy some of the biggest job and investment benefits, while the Victorian Government’s state target is expected to drive more project activity once finalised and legislated.

    http://reneweconomy.com.au/record-7-5bn-renewables-spend-puts-ret-well-within-reach-37388/

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    Tesla's revenue more than doubles, helped by record deliveries


    Electric-car maker Tesla Inc (TSLA.O) on Wednesday reported first-quarter revenue that more than doubled, and while saying the upcoming Model 3 was on schedule for July, it downplayed the mass-market vehicle to give a sales pitch for its more expensive Model S.

    Chief Executive Elon Musk's bold approach to cars, space exploration and clean energy has fueled investor enthusiasm for Tesla. But skeptics are waiting to see if Musk can fulfill his promise of producing 500,000 cars per year in 2018, or six times Tesla's 2016 production.

    Shares were down about 2 percent in after-hours trade following the results.

    The automaker's comments underscored the additional challenge of keeping up demand for its older models.

    "We have seen some impact of Model S orders as a function of people being confused" that Model 3 is the upgrade to Model S, Musk said on a conference call.

    Tesla said it had $4 billion of cash on hand as it headed into the second quarter and expects year-to-date capital expenditures to be slightly over $2 billion by the time it starts Model 3 production - within its previous targeted range of $2 billion to $2.5 billion.

    That cushion should give the company some near-term breathing room from needing to tap Wall Street for cash, said CFRA Research analyst Efraim Levy. Tesla in March raised $1.2 billion from the markets.

    Record deliveries helped Tesla boost its revenue to $2.7 billion in the quarter, but a net loss net widened to $330.3 million from $282.3 million a year earlier, largely driven by its SolarCity acquisition.

    Tesla has much riding on the Model 3, which could finally make the cash-hemorrhaging automaker profitable. But while much of the company hype has focused on the car due in July, Tesla on Wednesday made a sales pitch for its overshadowed Model S.

    Tesla is anxious that the $35,000 Model 3 - which will likely not be delivered in volume until 2018 - avoids cannibalizing the higher-margin Model S, which lists at about double the starting price.

    CHALLENGES AHEAD

    In its earnings release, Tesla stated that a key challenge for the company would be to eliminate misperceptions about the differences between the Model S and the Model 3.

    "We want to be super clear that Model 3 is not version three of our car. Model 3 is essentially a smaller, more affordable version of the Model S with fewer features," Musk said on a conference call, adding buyers erroneously thought the Model 3 would be more advanced.

    "The Model S will be better than Model 3," he added. "As it should be, as it's a more expensive car."

    Tesla needs to ramp up for a deluge of Model 3 customers, and the company said it would be adding nearly 100 retail, delivery and service locations worldwide, representing a 30 percent increase. Tesla also said it was also working to improve efficiency, citing vehicle repair times that have fallen by 35 percent due to the use of remote diagnostics.

    The company reiterated its forecast of delivering 47,000-50,000 Model S and Model X cars in the first half of 2017, a target it announced earlier this year.

    Still, customer deposits fell 7 percent in the quarter, which could suggest interest in Tesla's current product line, the Model S and Model X, is decreasing.

    On a per-share basis, Tesla's net loss narrowed to $2.04 from $2.13.

    Excluding items, the company lost $1.33 per share. Analysts on average had expected a loss of 81 cents per share, according to Thomson Reuters I/B/E/S.

    Tesla's results reflect the first full quarter that includes solar panel installer SolarCity, which it bought last year.

    The Silicon Valley-based automaker last month became the most valuable U.S. carmaker by market capitalization, pulling ahead of Detroit's auto heavyweights Ford Motor Co (F.N) and General Motors Co (GM.N).

    http://www.reuters.com/article/us-tesla-results-idUSKBN17Z2GK

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    Designed for defence, renewable-energy buoy makes waves at OTC


    Ocean Power Technologies parked its wave-powered buoy outside the Offshore Technology Conference that began May 1, 2017. (Collin Eaton)

    Somewhere off the coast of Japan, a 40-foot buoy is bobbing and weaving in the ocean, dancing with the waves to generate its own electricity.

    As it slowly gyrates, a floating platform heaves up and down the tall stalk, rotating an internal power generator that can feed up to 150 kilowatt hours of electric power into a large battery, which can charge an autonomous underwater vehicle like a Tesla charging station refuels a car.

    Its owner, New Jersey-based Ocean Power Technologies, parked an identical giant yellow buoy just outside the NRG Center in Houston this week, hoping to strike up business with oil companies at the Offshore Technology Conference.

    Before it found its way to Houston, the U.S. Navy had deployed the buoy half a dozen times off the coast of New Jersey, in tests designed to extend the range of its coastal surveillance. The buoy powered high-frequency radar and sonar technology that probes the ocean for hidden vessels, on the ocean’s surface and below it.

    “Unmanned underwater vehicles can be armed with bad stuff, and could be sent 50 miles away from the U.S. coast with no way to detect them,” said Mike Mekhiche, executive vice president at Ocean Power Technologies. “You could deploy this thing (the buoy) 200 miles offshore, put all kinds of sensors on it, and have a cost-effective surveillance means to detect vehicles we can’t detect today.”

    The U.S. Navy funded the first iteration of the buoy in 2009. The idea was that the radar and sonar sensors would collect data off the coast of New Jersey and send it to onshore stations. In theory, it could spot things like narco-submarines, narcotics-filled vessels that typically travel from South America.

    Now, the renewable energy company is trying to commercialize the technology. The buoy could, for example, power subsea oil and gas equipment for three years without requiring any maintenance, or recharge AUVs — essentially, underwater drones — that monitor deep-sea drilling operations, Mekhiche said.

    http://fuelfix.com/blog/2017/05/02/designed-for-defense-renewable-energy-buoy-makes-waves-at-otc/
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    Agriculture

    Fertilizer maker CF Industries' profit beats estimates


    U.S. nitrogen fertilizer producer CF Industries Holdings Inc (CF.N) reported a better-than-expected adjusted profit on Wednesday, as higher production offset lower fertilizer prices.

    The Deerfield, Illinois-based company's shares rose about 4 percent to $26.50 in after-hours trading on the New York Stock Exchange.

    "Strong early season demand for ammonia and urea ammonium nitrate (UAN) in the Southern Plains and lower Midwest," led to higher sales volumes in the first quarter ended March 31, the company said.

    Total sales volume by product tons of ammonia rose to 920,000 in the quarter from 737,000, while that of urea increased to 958,000 from 919,000.

    Fertilizer prices have faced pressure from weakening U.S. farmer incomes. The average selling price for ammonia fell about 18 percent to $307 per ton, while urea's decreased to $248 per ton from $256 a year earlier.

    Net loss attributable to shareholders was $23 million, or 10 cents per share, compared with a profit of $26 million, or 11 cents per share, in the year-earlier period.

    Excluding items, CF earned 5 cents per share, beating the average analyst estimate of 2 cents, according to Thomson Reuters I/B/E/S.

    Net sales rose marginally to $1.04 billion from $1 billion.

    http://www.reuters.com/article/us-cf-industries-results-idUSKBN17Z2K5

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    Bunge profit slumps on weak agribusiness margins


    U.S. agricultural trader Bunge Ltd (BG.N) reported a fall in its first-quarter profit as weak demand from South America weighed on margins in its agribusiness.

    Earnings before interest and tax in Bunge's agribusiness segment — which makes money buying, selling, storing, processing and transporting crops around the world — fell more than 61 percent to $109 million.

    Low grain prices and abundant global grain stocks have eroded margins for agribusinesses including Bunge and rivals Archer Daniels Midland Co (ADM.N), Cargill Inc [CARG.UL] and Louis Dreyfus Corp [LOUDR.UL].

    The companies, collectively known as the ABCDs, dominate the global grain trading business.

    "The slow pace of farmer selling in South America compressed margins in agribusiness and led to a lower-than-expected first quarter," Bunge's Chief Executive Soren Schroder said in a statement.

    However, the company said it expects "solid earnings growth" this year.

    Farmers in Brazil and Argentina are harvesting bumper corn and soybean crops this year, in contrast to 2016, when weather-reduced South American crops prompted farmers to hold back.

    Net income available to Bunge's shareholders fell to $39 million, or 27 cents per share, in the first quarter ended March 31, from $222 million, or $1.54 per share, a year earlier.

    On a per share basis, profit from continuing operations was 31 cents in the latest reported quarter, down from $1.60 per share, a year ago.

    http://www.reuters.com/article/bunge-results-idUSL4N1I52LR
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    Precious Metals

    Central bank gold demand slides to near six-year low in first-quarter: WGC


    Central bank gold demand hit its lowest in nearly six years in the first quarter as Chinese buying dried up, the World Gold Council said in a report on Thursday, feeding into an 18 percent year-on-year drop in overall demand.

    The official sector added just 76 tonnes of bullion to its holdings in that period, the industry-funded WGC said in its latest Gold Demand Trends report, down by more than a quarter from a year before and the lowest of any quarter since Q2 2011.

    China, a major official sector buyer of gold in recent years, has held off making any additions to its reserves since October, the first time it has done so since it started releasing quarterly reserves data in 2015.

    A focus on capital outflows may have been weighing on the Chine2se central bank's interest in gold, the WGC's head of market intelligence Alistair Hewitt said.

    "China's forex reserves have declined significantly over the last 18 months, edging beneath $3 trillion at the start of this year," he said. "At the same time gold as a percentage of FX reserves has increased. That is partly a function of the decline in FX reserves and also the increase in the gold price."

    The WGC is forecasting central bank purchases of 250-350 tonnes this year, he said, down from 377 tonnes in 2016. Russia and Kazakhstan are expected to remain buyers of gold.

    The first-quarter drop in central bank buying fed into an 18 percent fall in global gold demand to 1,034.5 tonnes, the weakest first quarter since 2010, the WGC said.

    Investment in gold-backed ETFs slipped back from the previous year's record levels, though it held firm at 109 tonnes, versus selling of 193 tonnes in the previous quarter.

    Balancing that, global jewelry consumption, the single largest demand segment, was a touch higher, while coin and bar demand rose 9 percent.

    Chinese consumer demand edged up 8 percent to 297.3 tonnes as higher coin and bar demand offset softer jewelry offtake, while Indian demand also rose 15 percent to 123.5 tonnes as the impact of demonetization eased, releasing pent-up demand.

    Chinese demand is forecast to reach 900-1,000 tonnes this year, against 913 tonnes last year, while Indian consumption is forecast at 650-750 tonnes, against 660 tonnes in 2016, the WGC said.

    http://www.reuters.com/article/gold-demand-wgc-idUSL8N1I565I
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    Base Metals

    Copper Is Crumbling After Stockpiles Surge

    Copper Is Crumbling After Stockpiles Surge

    After reaching one month highs on Monday, copper futures prices have tumbled to near 3-week lows amid slowing China credit impulse-driven economic signals (PMIs weak) and a surge in LME stockpiles.

    And the market reacted...

    Additionally, as Bloomberg reports, There are also more signs of slack spot demand: immediate delivery copper’s discount to the three-month contract on the LME has widened 28 percent this week. Bigger inventories and the loosening of the copper price curve are at odds with forecasts that the copper market will move into deficit this year, Leon Westgate, an analyst at Levmet U.K. Ltd., said by phone.

    “Judging by the price action and the movement in the spreads, it looks like the market might have been anticipating these deliveries,” he said.

    As Guy Wolf, a London-based analyst at Marex Spectron Group, noted:

    “It is about whether the tide of liquidity is going in or out, not the latest anecdote about Chinese demand or comment from a Chilean union official.”

    “We think we’ll see a more sizable slowdown out of China,” says Edward Meir, an analyst at INTL FCStone in NY
    “We’re a little bearish on copper for May”

    http://www.zerohedge.com/news/2017-05-03/copper-crumbling-after-stockpiles-surge
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    Southern Copper profit rises 70% on higher metals prices


    Southern Copper on Wednesday reported net income of $314.4-million for the first quarter, up 70% from $185.1-million a year earlier and 82% above the $172-million posted in the fourth quarter of 2016.

    Southern Copper, owned by Grupo Mexico, is one of the world's largest copper producers and operates mines in Mexico and Peru. The increase in profit came as copper prices rose 25% and zinc prices rose 65.8%, the company said.

    A two-week strike last month at its Toquepala and Cuajone copper mines as well as its Ilo refinery in Peru reduced copper production by 1 418 t, Southern Copper said in its earnings report. The two mines together produced 310 000 t of copper last year, according to government data.

    Net sales grew 27.2% to $1.6-billion, while the cost of sales grew 16.1% to $843.8-million, Southern Copper said. The company's capital investments grew 10% to $245.6-million due to a plan to boost copper output at Toquepala by 100 000 t to 260 000 t by 2019.

    With the expansion, Southern Copper will produce one-million tonnes in 2019, compared with 900 000 t produced last year, chairperson German Larrea said.

    http://www.miningweekly.com/article/southern-copper-profit-rises-70-on-higher-metals-prices-2017-05-04

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    German copper group Wieland buys U.S. tube business


    German copper products group Wieland said on Wednesday it has taken over the copper and steel tube business of U.S. company Wolverine Tube Inc, as part of its plans to expand internationally.

    Unlisted Wieland gave no financial details of the deal, which will see it acquire Alabama-based Wolverine's manufacturing of finned and enhanced surface tubes from copper, copper alloys and steel alloys.

    "In line with our corporate strategy, this acquisition is another important step on the way to expand Wieland Group's international market position," Wieland CEO Erwin Mayr said in a statement. "It allows us to strengthen our portfolio of high-end, technically differentiated businesses."

    One major use of the finned and enhanced surface tubes is energy-efficient coolant transfer in large air conditioning systems for buildings, a Wieland spokeswoman said.

    The company did not give any details of the business's tonnage or turnover.

    Mayr became Wieland CEO on April 1 and has said he plans to expand the group's international presence.

    Wieland sells around 440,000 tonnes of copper products a year with annual sales of around 2.7 billion euros ($2.9 billion) and has operations in Europe, North America and Asia.

    http://www.reuters.com/article/us-copper-germany-wieland-idUSKBN17Z0VN
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    Philippines' congress panel rejects Lopez as environment minister


    Philippine lawmakers on Wednesday rejected the appointment of Regina Lopez as environment minister, 10 months into her term in office, confirming an earlier Reuters report.

    The Commission on Appointments moved to reject the appointment made by President Rodrigo Duterte who has largely supported Lopez's mining crackdown. Lopez was the second member of Duterte's cabinet dismissed by Congress.

    Congressman Ronaldo Zamora earlier told Reuters about the outcome of the vote, which removed Lopez.

    Lopez angered the mining sector after ordering in February the closure of more than half the country's mines and the cancellation of dozens of contracts for undeveloped mines to protect water resources. Last week, she banned open-pit mining.

    Cabinet ministers in the Philippines undergo a confirmation hearing, often long after they begin work.

    http://www.reuters.com/article/philippines-mining-vote-idUSP9N1GC00Q
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    Steel, Iron Ore and Coal

    Henan to stop approving new coal mine projects over 2016-18


    Henan province in central China pledged to stop giving approval for new coal mine projects and projects of technical upgrading and capacity expansion for newly-added coal production capacity over 2016-2018, said the provincial government in a notice released on April 26.

    If it is necessity to build new coal mines, capacity replacement should be carried out to avert unreasonable expansion, according to the notice.

    The province plans to shed 39.63 million tonnes per annum (Mtpa) of coal production capacity by closing 158 coal mines during the next two years, said the provincial Development and Reform Commission on its website December 11.

    It will close mines that fail to obtain licenses or use mining methods prohibited by the government. Meanwhile, those mining coal in natural reserve areas, water conservation protection zones and scenic spots would also be shut down.

    http://www.sxcoal.com/news/4555539/info/en
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    European steel M&A heats up even for loss-making plants


    In late 2015, the steel industry - a gauge of the world's economic health - was on the ropes. Record Chinese exports, excess global capacity and shrinking demand had pushed prices to decade lows, forcing closures, lay-offs and bankruptcies.

    The picture couldn't look more different today. Thanks to China's decision to dramatically cut capacity while boosting infrastructure spending, added to the improved outlook for global growth and increased protectionism, prices have surged some 45 percent since December 2015.

    A boom in mergers and acquisitions has followed, with investors competing to fork out billions for steel companies once considered nigh on worthless.

    Germany's Thyssenkrupp (TKAG.DE) struck a deal in February to sell money-losing Brazilian steel mill CSA to Ternium SA (TX.N) for $1.3 bln. India's Tata Steel (TISC.NS), which threatened to shut its loss-making UK assets last April, is now in talks to merge its UK and European plants with those of Thyssenkrupp.

    But perhaps the starkest example of the turnaround is in the bidding war for Ilva, in Taranto, southeast Italy.

    Europe's largest and most troubled steel plant, Ilva has racked up hundreds of millions of euros worth of losses since coming under government stewardship in 2013.

    The plant has been dogged by charges of corruption and environmental crime for years. In 2012, Italian authorities ruled emissions of dust and cancer-causing chemicals from the plant caused hundreds of deaths and abnormal levels of tumors and respiratory disease in the Taranto region.

    About half the plant's 11-million-tonne annual steelmaking capacity was eventually mothballed, senior managers and executives were arrested and 8 billion euros of assets were seized from the Riva Group, Ilva's former owners.

    Yet two consortiums - one including ArcelorMittal .ISPA.AS, the world's top steelmaker, and the other involving Indian steelmaker JSW (JSTL.NS) - are now vying to spend around 4 billion euros buying, upgrading and cleaning the plant, betting that imports into Europe will decline just as the economy picks up.

    It's a bet worth making, steel executives say.

    "With reduced import volumes, Ilva's additional output will be absorbed. The domestic market is not booming but it is growing, and we should continue to see a steady increase in industrial activity in Europe," Tommaso Sandrini, president of Italian steel processors association Assofermet, told Reuters.

    Renewed M&A activity is expected to lead in turn to capacity cuts which will further boost prices, they say.

    Of the Tata merger, Thyssenkrupp's chief financial officer Guido Kerkhoff said: "The most important thing for us is that by a consolidation ... we can address the issues of overcapacity."

    CHINA CAPACITY CUTS

    As with so many sectors of the global economy today, China is the key to the reversal of steel's fortunes.

    The world's top steel maker in early 2016 said it would to cut 100-150 million tonnes of steel capacity by 2020 as part of efforts to tackle pollution and curb excess supply.

    It cut 60 million tonnes of steel capacity last year alone, according to official figures, and has announced plans to cut another 50 million tonnes this year.

    The cuts coincide with a 700-billion-dollar stimulus splurge targeted at infrastructure and construction that prompted a 73 percent jump in Chinese steel prices SRBcv1 last year and a 3.5 percent fall in Chinese exports. >

    Exports have dropped a further 25 percent this year.

    Soaring prices have translated into big gains for steel company shares. Global steel equities .TRXFLDGLPUSTEL are up 80 percent since plumbing 12-year lows last January.

    The World Steel Association expects steel demand in developed economies to grow 0.7 percent this year and 1.2 percent next, with eurozone interest rates and tax policy set to remain on a steady course and the United States seen benefiting from tax cuts and rising infrastructure spending.

    Factories across the euro zone increased activity in March at the fastest rate in nearly six years, official figures show.

    "We have in front us years of sustainable profits for European producers," said Sandrini, who is also chief executive of Italian steel processor S.Polo Lamieri.

    THROWING UP BARRIERS

    European steel lobby Eurofer says local steelmakers are finally set to benefit from the demand growth this year thanks to the cumulative impact of anti-dumping measures.

    The EU currently has 39 anti-dumping and anti-subsidy measures in place on steel, 17 directed at China and most of which have been put in place over the past couple of years.

    Across the pond, U.S. steelmakers are getting an even more pronounced boost from a string of steel trade barriers put in place under the Barack Obama administration which are poised to multiply under President Donald Trump.

    The Trump administration said last month it will invoke a seldom-used provision of law to launch a probe into whether imports of Chinese and other foreign-made steel are a U.S. national security risk.

    That will come on top of some 150 anti-dumping and anti-subsidy duties already in place on steel imports, according to the Cato Institute, a think tank.

    China's exports to the United States fell 56 percent last year, mostly due to these measures, some of which are as high as 500 percent, according to the International Steel Statistics Bureau.

    "The Chinese are now out of the (steel export) game and many other countries will be out too, considering the number of anti-dumping investigations in place," Sandrini said.

    Berenberg analyst Alessandro Abate told Reuters Ilva's privatization alone will see EU steel prices rise by 10-20 euro per ton as regional buyers pay a premium for supply which, relative to imports, is of higher quality and can be delivered quickly and reliably.

    The new owners of Ilva and of the Tata-Thyssenkrupp assets are also expected to employ a more disciplined pricing strategy going forward - holding out for higher prices and taking pains not to over-supply the market, unlike in the past when Ilva, and to a lesser extent Tata, favored volumes over price.

    Alistair Ramsay, research manager at Metal Bulletin Research (MBR), said he disagreed with talk of "peak steel demand", and pointed to consistent annual imports into Europe over the past few years of 5 million tonnes of hot rolled coil, the main steel product used by white goods manufacturers.

    "If you've got a duty to place against those imports, then suddenly that steel must be found somewhere else," Ramsay told Reuters. "If one has control of Ilva and there's a bit more control over EU borders, its potentially a pretty lucrative situation."

    http://www.reuters.com/article/us-steel-m-a-global-idUSKBN17Z0VR
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    India's cabinet makes local steel mandatory in govt projects


    India's cabinet on Wednesday approved a proposal to make the use of local steel mandatory for government's infrastructure projects, Finance Minister Arun Jaitley said, aimed at boosting the sales of local companies.

    The ministry's flagship National Steel Policy, which seeks to outline a roadmap to increase the country's annual steel production to 300 million tonnes by 2025, was also passed by the cabinet, Jaitley said.

    An official with direct knowledge of the matter told Reuters earlier that Prime Minister Narendra Modi's cabinet might clear the proposals.

    The policy is broadly seen as a continuation of India's protectionist stance against countries such as China and Russia.

    It also comes in the backdrop of a trade probe launched by U.S. President Donald Trump against cheap imports into the United States, in a move that could aggravate trade friction among global producers.

    India wants to nearly triple its production capacity by the next decade and acquire technology to produce higher value products including automotive steel.

    The government policy will also provide a guiding light for Indian steel companies that are seeking to expand while saddled with huge debts.

    In March, Reuters had reported the steel ministry was considering a move making it mandatory to use local steel - pitching it as a WTO-compliant move.

    India is also expected to soon announce long-term duties on some steel products imported from China, Japan and Russia, despite complaints from some of the targeted countries.

    Between April and March, India's steel imports fell 37 percent year-on-year, data from a government body showed, primarily due to measures announced by the government.

    The proposed National Steel Policy, which was floated in October by Niti Aayog, an influential government think-tank that replaced the Planning Commission, recommended measures to also reduce dependence on imported coking coal, lack of which recently crippled production after heavy rains in Australia created shortages.

    http://www.reuters.com/article/india-steel-idUSL4N1I5250
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