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CMOP

CMOP

US - update through September 2018

This interactive presentation contains the latest oil & gas production data from 97,332 horizontal wells in 10 US states, through September 2018. Cumulative oil and gas production from these wells reached 9.7 Gbo and 106 Tcf. West Virginia is deselected in most dashboards, as it has a greater reporting lag. September production data for New Mexico is rather incomplete, with over 100 thousand bo/d still missing. Visit ShaleProfile blog to explore the full interactive dashboards   After all revisions are in, oil production from these horizontal wells should come in well above 6 million bo/d for September. The ~8,000 wells that started in the first 9 months of 2018 will then already have contributed ~3 million bo/d in September. Never before in the history of US shale was so much new production capacity added in 9 months. As the total decline of older wells (<2018) was over 2 million bo/d (as shown by the top of the light blue area) in this period, the actual growth rate was a little below 1 million bo/d. If you switch to natural gas (using the ‘Product’ selection), you’ll see that gas production from the same wells never really experienced a drop, and grew by ~15 Bcf/d in the past 2 years to 55 Bcf/d (excluding WV) in September.   Initial well productivity grew steadily over the past 10 years (‘Well quality’ tab), but the rate of improvements appears to have slowed down recently.   You’ll find the status of the more than 100,000 horizontal wells that have been drilled in the ‘Well status’ tab. Only 1% of these wells have been plugged and abandoned so far.   The final dashboard gives an overview of the largest operators. EOG is well in the lead, with around 0.5 million bo/d of operated production capacity. Its September production numbers for New Mexico are highly incomplete, so the final drop should be ignored. The ‘Advanced Insights’ presentation is displayed below: This “Ultimate recovery” overview shows the relationship between production rates and cumulative production over time. The oil basins are preselected, and the wells are grouped by the year in which production started. The 4,300 wells that started production in 2011 (represented by the red curve) peaked at a rate of 273 bo/d, and they have now declined to 22 bo/d, recovering almost 150 thousand barrels of oil in the meantime (all average numbers). The 5,300 wells that started 5 years later (2016 – light brown curve), peaked at 517 bo/d, and they already recovered the same amount of oil within 22 months, on average. They are on a trajectory to do roughly another 100 thousand barrels of oil, before having declined to a similar production rate of ~20 bo/d. More granular and recent data will be visible after grouping these wells by the quarter or month in which they started production.   Next month we will be at the NAPE summit in Houston. Come visit our booth if you have the chance! Before the NAPE we plan to start offering the Basic version of our ShaleProfile Analytics service. For just a very small annual fee ($624 = $52/month) you can already enjoy all the benefits that this service offers beyond the free blog here, such as maps with the exact location of these wells, full-screen dashboards, and with always access to the latest data.   Early next week we will have a new post on North Dakota, which just released November production data. Production data is subject to revisions. For these presentations, I used data gathered from the sources listed below. FracFocus.org Colorado Oil & Gas Conservation Commission Louisiana Department of Natural Resources. Similar as in Texas, lease/unit production is allocated over wells in order to estimate their individual production histories. Montana Board of Oil and Gas New Mexico Oil Conservation Commission North Dakota Department of Natural Resources Ohio Department of Natural Resources Pennsylvania Department of Environmental Protection Texas Railroad Commission. Individual well production is estimated through the allocation of lease production data over the wells in a lease, and from pending lease production data. West Virginia Department of Environmental Protection West Virginia Geological & Economical Survey Wyoming Oil & Gas Conservation Commission   Visit our blog to read the full post and use the interactive dashboards to gain more insight http://bit.ly/2HgzW2F   Follow us on Social Media: Twitter: @ShaleProfile
Linkedin: ShaleProfile
Facebook: ShaleProfile

shaleprofile

shaleprofile

 

Capital Markets... Dive in Now?

The recent market volatility has left investors and capital seekers seeking he same consensus: where does it end and what's the upside?  The age old question continues to perplex both parties.  I'm taking the position from both sides.. first as a former exploration company President who had sought capital from the banks, from P/E firms, mezzanine debt and from the public markets and secondly as a capital provider.  We currently manage substantial amounts of capital that are looking to deploy into the energy sector, so being on both sides in a past and current life, I speak from experience. Oil and gas companies that seek us out for capital come in a number of flavors and sizes.  Typically, they are smaller entities, or juniors.  This is our financing niche.  Their needs are the usual: drill PUDs, re-work, acquire non-cores, get a leg up on OPEX and generally seek growth in fractious times.  In nearly every case, the banks are exhausted as much as the juniors are.  These companies are far too small for the P/E firms to get involved and the old 'Third for a quarter' deal won't cut it.  What to do? As a capital provider, we seek to obviously entreat the best companies we can to provide this dearly needed money.  Some have said that the smaller deals that come in to any facility seeking capital are the deals no one else will touch.  We disagree.  The old saying, "Oil and gas doesn't care who owns it,' serves a point.  Economies of scale are persistent relative to size.  Nearly all the companies we review are sitting on oil, and what better place to produce from than an existing field?  Have the production and a good development plan?  Are these good oil people with a solid history of exploration and exploitation?  We take these into account, among other things as we review and allocate due diligence resources to determine if the underpinnings are there and there's sufficient existing PDPs to support the capital raise over a term. A word about the raise.. it's non-recourse, not a loan, off balance sheet, no equity take out and there's no back-in after payout. Oil companies seek a better, more efficient way to utilize and pay back capital and there is a better way than the old tried and perhaps not so true way... In these times, we feel a floor has been reached and tested market wise.  Wise firms can access wise money now, versus looking for it when the recent 30% drop has been recovered and capital costs and service costs will likely erode portions of this gain. Companies can't afford to hand wring now... it's time to set up for the future and plan capex budgets now.         

Pt.3 The Media - Information sources - Electric/Hydrogen/Natural Gas Vehicles/ Nuclear Energy

Pt.3 The Media - Information sources - Electric/Hydrogen/Natural Gas Vehicles/ Nuclear Energy "Oh dear". This blog is about how to engage positively and effectively with the Media (TV, Radio, Press, Social Media, Bloggers. Vloggers) - mainstream, regional, local, international - from my own "mainstream" experience: e.g. BBC World Service.    The content I use will be controversial and often, given that this is a fossil fuels website, not pleasing to some. All the content is sourced and available in the mainstream Media. My consultancy work is giving Media advice to all industry sectors, face-to-face and via Skype - e.g. DHL. KIA Motors, Nord Stream, UK Independent Schools' Council.  The different Media, like individuals, will often choose the sources of information that reflect their wishes, values and bias. Thus, understanding the (often political) agenda of different Media before you or your company engages with them is extremely important.  Two key professional interests of mine are: 1. Investigating why the Fossil Fuel Industry has never fought back against claims such as: - it is destroying the planet and that CO2 emissions are a Climate problem - "Big Oil" is throwing money to Climate Sceptic individuals and organisations; which is demonstrably not so, but is the result of a clever and long-term campaign by Greenpeace who targetted Exxon some years ago to label it "Evil Empire". 2. The philosophy of science: especially Popper v Kuhn.  Posts will not normally be this long, but here are a few bullet points with regard to the above title and in relation to various comments:   Fossil fuels: - yes, pollution is a factor and is increasingly being limited - CO2, however, is not a pollutant and is vital for life on Earth. - produced and are still producing the high standard of living we expect and want - are not subsidised everywhere, and the use of them is usually very highly taxed to provide national governments with a massive source of income for public services - there are different grades of all these fuels; varying down to low-level pollutants - even coal can be non-polluting: e.g. Professor Rosemary Falcon heads the Sustainable Coal Research Group at the University of the Witwatersrand (Wits), Johannesburg (where Nelson Mandela studied law in the 1950's).   LPG/LNG vehicles: I too drive an LPG vehicle and gas, having done so for years   Renewables:  - are all subsidised and paid for by taxpayers either in their domestic energy bills and in the government subsidies - often both - produce less energy than was used to manufacture, erect and dismantle them after their short life (20-30 yrs). These three processes create large amounts of industrial pollution.    Global energy needs are expected to increase by 250% by 2050 as living standards rise. Estimates vary on global energy use and production - e.g. in 2017 renewables produced 8% of global energy according to BP. The most optimistic projections from the pro-renewables IEA estimate that by 2040 renewables will still represent only 30% of global energy production - and of that the biggest contributors will be Hydro-Electric Power and Waste, not the beloved wind and solar sources. Sources are contradictory and confusing because of inherent political (not scientific) agendas).  On average it seems that global energy use has risen by 150% in the last 20 years, and as a percentage of energy production the world is even more reliant on fossil sources than before.   Solar panelscannot be simply buried in landfill because they contain toxic chemicals such as lead, cadmium, antimony; the glass is usually not pure enough to recycle; plastics are an integral part of construction. The problem of solar panel disposal “will explode with full force in two or three decades and wreck the environment”because of  "a huge amount of waste and they are not easy to recycle. Contrary to previous assumptions, pollutants such as lead or carcinogenic cadmium can be almost completely washed out of the fragments of solar modules over a period of several months, for example by rainwater.” Sources:  (http://www.scmp.com/news/china/society/article/2104162/chinas-ageing-solar-panels-are-goingbe-big-environmental-problem) 40-year veteran of US solar industry  (https://www.solarpowerworldonline.com/2018/04/its-time-to-plan-for-solar-panel-recycling-inthe-united-states/) (https://www.welt.de/wirtschaft/article176294243/Studie-Umweltrisiken-durch-Schadstoffe-in-Solarmodulen.html) Research scientists - German Stuttgart Institute for Photovoltaics.   The International Renewable Energy Agency (IRENA) in 2016 estimated there were  about 250,000 metric tonnes of solar panel waste in the world at the end of that year. IRENA projected that this amount could reach 78 million metric tonnes by 2050. (http://www.irena.org/publications/2016/Jun/End-of-life-management-Solar-Photovoltaic-Panels)   Wind power is even less efficient than solar for all the production reasons above and is more unpredictable as an energy source; kills flying creatures to such an extent that in some areas it has become the "apex predator" where it takes out birds of prey. Nuclear towers do not create such carnage because they do not move and are highly visible.   Nuclear Energy is the cleanest, safest and most reliable energy source we have. When there are problems they can certainly be on a large scale (Three Mile island, Chernobyl, Fukushima) but result in very few deaths. If you consider CO2 to be a major problem, nuclear energy produces none at all. Ironically, this year (2018) the floating wind turbine erected as at Fukushima as a symbol of renewal is being dismantled because of its high maintenance costs.  "The price tag to remove the ¥15.2 billion turbine, which has an output capacity of 7,000 kilowatts, is expected to be around 10 percent of the building cost. Studies on the two other turbines are due to conclude in fiscal 2018, but the study period is expected to be extended to seek any possibility of commercialization. ... Its utilization rate over the year through June 2018 was 3.7 percent, well below the 30 percent necessary for commercialization. The two other turbines, of different sizes, have utilization rates of 32.9 percent and 18.5 percent, respectively." Source: Japan Times   Nuclear "waste" is in fact a resource and not to be feared! " ... fission waste does not migrate even where there is significant groundwater, and ... ancient waste had none of the multi-layer engineered safeguards that are now developed, nor the careful geological siting." " by far the biggest resource in radwaste is in the transuranics and unburnt uranium. This could be used to increase the energy available from nuclear fuel by several orders of magnitude using fast breeder reactors, but such use is no longer being pursued in many countries, including the UK ([which] used to be the world leader up until the early 1980s), as uranium is too cheap to make it economically attractive at present." Source: Rolls Royce expert and recipient of the Institute of Physics Nuclear Industry Group Lifetime Achievement Award   And no, it can't be used to make a nuclear bomb; and there are much easier ways for terrorist groups to make the usual "dirty" bombs than trying to get hold of nuclear residue. It is calculated that there are about 120,000 cubic metres of nuclear waste in the world - i.e. not enough to fill a soccer stadium, since the start of the nuclear industry in the 1950's. Nuclear use is already part of our daily lives. We already use radio cobalt in irradiating food and medical supplies; strontium or plutonium for generators in space travel; americium in smoke detectors; tritium in emergency-exit signage; various radio isotopes are used to diagnose and treat diseases.  Soon it is expected that we will be able to split further uranium isotopes and all uranium's heavy metal derivatives.  Given that my first interest is helping you and your company to deal with the Media, mainstream and otherwise, it is important to judge your audience and then tailor your information to help them take it in.  My presumption so far here in this blog is that readers are well-informed, wish to be given reasons to reflect, think and debate civilly on what are very important matters affecting how we live. I also presume such readers are thinkers rather than activists. Trigger warning: further topics will include references to and buzz words such as coal, climate change, CO2, sea levels, non-AGW, geological time scales, IPCC, Greenpeace, Big Oil and the like.

Roger Crisp

Roger Crisp

Permian – update through September 2018

This interactive presentation contains the latest oil & gas production data from all 17,997 horizontal wells in the Permian (Texas & New Mexico) that started producing since 2008/2009, through September. Visit ShaleProfile blog to explore the full interactive dashboards Last week I planned a post on the Permian, but noticed that September data for New Mexico was still quite incomplete (100 kbo/d, or ~20% of production has not yet been reported). Unfortunately, it still is, but I did not want to delay this update any further. The graph above shows clearly the astonishing rise in oil production in the Permian in the past 2 years, as oil production from horizontal wells more than doubled to over 2.8 million bo/d in September (which will be visible after upcoming revisions). More than 1.5 million bo/d in September came from ~3,200 horizontal wells that started in 2018. In New Mexico a single operator seems to be responsible for most of the missing production in September: EOG, which is also the largest producer in this state. After you exclude EOG from the graph (using the ‘Operator’ selection), you will see that the apparent drop in September has almost disappeared.   In the ‘Well quality’ tab you’ll find the production profiles for all these wells. By default they are grouped and averaged by the year in which they started production. With this setting, you’ll find in the bottom plot that well productivity improved significantly in the past 5 years. Wells that started in 2013 recovered 77 thousand barrels of oil in the first 2 years, on average, while this more than doubled to 183 thousand barrels of oil for wells that started 3 years later. Since 2016 the pace of improvements appears to have slowed down, as you’ll see by following the 2017/2018 curves.   The final tab shows the performance of the leading operators. You’ll see the effects of the acquisition of RSP Permian by Concho, and the missing production for EOG in New Mexico in September. The ‘Advanced Insights’ presentation is displayed below: This “Ultimate recovery” overview shows the average production rate for these wells, plotted against their cumulative recovery. Wells are grouped by the year in which production started. This kind of plot doesn’t assume any kind of decline behavior, but a harmonic decline (b factor of 1), will show up as a straight line with the given settings. The 2,215 horizontal wells that started in 2016 (light brown curve) are on track to recover each around 200 thousand barrels of oil, once they have declined to an average production rate of 100 bo/d. Newer wells appear to be on track to do slightly better than that. Tomorrow we will have a new show at enelyst (live chat combined with images), where we will take a closer look at the latest Permian data. The show will be available here in the enelyst ShaleProfile Briefings channel. If you are not an enelyst member yet, you can sign up for free at enelyst.com. Early next week we will have a post on all 10 covered states in the US. Production data is subject to revisions. Note that a significant portion of production in the Permian comes from vertical wells and/or wells that started production before 2008, which are excluded from these presentations. For these presentations, I used data gathered from the following sources: Texas RRC. Oil production is estimated for individual wells, based on a number of sources, such as lease & pending production data, well completion & inactivity reports, regular well tests and oil proration data. OCD in New Mexico. Individual well production data is provided. FracFocus.org   Visit our blog to read the full post and use the interactive dashboards to gain more insight http://bit.ly/2LUFMoY   Follow us on Social Media: Twitter: @ShaleProfile
Linkedin: ShaleProfile
Facebook: ShaleProfile

shaleprofile

shaleprofile

Eagle Ford - update through September 2018

This interactive presentation contains the latest oil & gas production data from all 21,698 horizontal wells in the Eagle Ford region, that started producing since 2008, through September. Visit ShaleProfile blog to explore the full interactive dashboards Although from the above graph it appears that oil production in the Eagle Ford has moved sideways in 2018, due to the typical reporting lag in Texas, I expect to see that after revisions production from horizontal wells will come in at 1.3 – 1.4 million bo/d in September. That would be highest level in the past 2.5 years, but still well below the 2015 peak.   One reason for that is that well productivity hasn’t increased so much in the past 4 years, as you’ll see in the ‘Well quality’ tab. This despite that laterals have gotten longer (by about 1/3rd), and more frac sand is typically used nowadays (it more than doubled). You’ll be able to normalize for these factors in our online Analytics service.   The basin is aging rather rapidly, and in September almost 80% of these horizontal wells were producing below 50 bo/d, as can be seen in the bottom plot of the ‘Well status’ overview. However, that number does include about 3,000 gas wells as well (filtering these is a subscription-only feature).   The 2 leading operators, EOG & ConocoPhillips, either set new production records in September, or were close (‘Top operators’).   The ‘Advanced Insights’ presentation is displayed below: In this “Ultimate Recovery” overview, the relationship between production rates and cumulative production is revealed. Wells are grouped by the year in which production started. I’ve preselected the Austin Chalk and Eagle Ford formations. As you can see, wells from the 2010-2012 time frame are now on average below 20 bo/d, after having recovered 120-150 thousand barrels of oil (and 0.7-1 Bcf of natural gas). Wells that started in 2017 peaked at a rate of 664 bo/d, and declined to a level of 174 bo/d in the next 8 months, having recovered just over 100 thousand barrels of oil. More recent and granular data can be found if you select to group the wells by quarter or month of first production (using the ‘Show wells by’ selection).   The WSJ just published an interesting article in which they compared actual verses operator reported well performance. Many of our subscribers and readers have told us that they value our services due to the independent and accurate reporting of production data. In February we will be at the NAPE summit in Houston, so please stop by our booth if you are joining this event as well.   Early next week we will have a post on the Permian again, on which we also have a more detailed update in our upcoming enelyst chat on Tuesday.   Production data is subject to revisions, especially for the last few months. For this presentation, I used data gathered from the following sources: Texas RRC. Production data is provided on lease level. Individual well production data is estimated from a range of data sources, including regular well tests, and pending data reports. FracFocus.org   Visit our blog to read the full post and use the interactive dashboards to gain more insight http://bit.ly/2s048ED   Follow us on Social Media: Twitter: @ShaleProfile
Linkedin: ShaleProfile
Facebook: ShaleProfile  

shaleprofile

shaleprofile

Marcellus (PA) – update through October 2018

This interactive presentation contains the latest gas (and a little oil) production data, from all 8,567 horizontal wells in Pennsylvania that started producing since 2010, through October. Visit ShaleProfile blog to explore the full interactive dashboards New production records have been set in the 2nd half of every year since 2010, and 2018 was no different. Gas production in October from horizontal wells came in at 17.6 Bcf/d, about 20% higher than October 2017 (14.1 Bcf/d). The 687 wells that started production in the first 10 months of 2018 already contributed more than 1/3rd of total gas production in October (6 Bcf/d).   Well productivity made a big gain in 2017 (see ‘Well quality’ tab), but it did not rise much further in 2018, based on preliminary data. Newer wells recover on average more than 4 Bcf in the first 2 years on production, compared with 3 Bcf from wells that started in 2016.   All major operators increased production in 2018, except Chesapeake (‘Top operators’). The ‘Advanced Insights’ presentation is displayed below: This “Ultimate Return” overview shows the relationship between gas production rates and cumulative gas production, averaged for all horizontal wells that came online in a certain year. The improved performance over the past years is clearly visible here. If you change the ‘Show wells by’ selection to ‘quarter’, you can see more recent and granular data. It will also reveal that newer wells peak at a level of over 12,000 Mcf/d, more than three times the rate of the wells that started in 2012.   The 2nd tab (‘Cumulative production ranking’), ranks all counties in Pennsylvania by cumulative gas production. If you change the ranking to ‘Well’, you’ll see the cumulative production for each of those 8,500+ wells. The most productive one is above 20 Bcf.   Later this week we will have a new post on the Permian. We wish you all a Happy New Year!   Production data is subject to revisions. For this presentation, I used data gathered from the following sources: Pennsylvania Department of Environmental Protection FracFocus.org   Visit our blog to read the full post and use the interactive dashboards to gain more insight http://bit.ly/2s048ED   Follow us on Social Media: Twitter: @ShaleProfile
Linkedin: ShaleProfile
Facebook: ShaleProfile  

shaleprofile

shaleprofile

 

Mombasa Port a gateway to South Sudan for China

Former Chinese Communist Party leader Deng Xiaoping presented his “Cat Theory” to introduce a capitalist market economy for Mainland China. As per the theory “It doesn’t matter if a cat is black or white;as long as it catches mice,it’s a good cat.” The “Cat Theory” which he put forth was to convince policy makers for the radical shift in economic policies. “Cat Theory” is also relevant if one looks at the way China is pursuing its geo-political interests using its economic clout. There is one more distinct quality about the cat which makes it a stealth killer. When the cat advances towards its prey it hides its claws.     Kenya is latest in a series of nations to feel the claws of Chinese debt. Latest report attributed to Auditor General suggests that strategic Mombasa Port could land up in the hands of Chinese Bank, EXIM Bank if Kenya fails to repay the loan amount. Though, the Audtior General Edward Ouko has issued a denial. But it does not mean that Mombasa port will not become Chinese one day as we have seen the example of how Sri Lanka handed over Hambantota port to China to pay off its debt. To sustain higher economic growth China needs unfettered access to raw materials for its factories and a market to export its finished goods. At a time when China is facing pressure from United States of America over trade,Africa offers tremendous opportunities for Chinese economy. Infrastructure investment in Africa reflects China’s decades-old strategy of using soft power. More recent investments in Kenya and Ethiopia represent an extension of the Chinese President Xi Jinping’s Belt and Road Initiative (BRI). BRI is a trillion-dollar investment strategy which focusses on developing transportation sector and infrastructure, particularly in Eurasia region but also in East Africa. The amount of Chinese loans to Kenya has grown tenfold in the five years since China unveiled its Belt and Road Initiative. In May 2014, Kenya and China inked Sh 327 billion railway line agreement. According to the terms of the agreement,China had to finance 85 per cent of the total cost through Export and Import (EXIM) Bank while Kenya had to bear the remaining 15 per cent of the projects’ cost. The rail line pened in May-2017. China financed Nairobi-Mombasa Railway link is touted as the biggest infrastructure project in the history of independent Kenya and is a part of Kenya Railways Corporation’s new Standard gauge railway (SGR) line. The Mombasa-Nairobi rail connectivity will cut down travel time by half. It will benefit passengers and cargo transportation. The SGR project is expected to link Mombasa to Rwanda with a branch line to Juba in  South Sudan in future. This Mombasa-Nairobi railway line will give China access to South Sudan in near future. The oil production of South Sudan is dominated by Chinese oil majors. China National Petroloeum Corporation (CNPC) pumps nearly all of South Sudan’s oil production. After cessation in 2011,both Sudan and South-Sudan are now mutually dependent on oil revenues for their economic survival. South Sudan is landlocked and has 75 percent of the oil reserves. The oil from the fields of South Sudan is transported through 1600 kms pipeline to reach export terminals in Port Sudan and then it reaches to refiners in China. On August 30th 2018 South Sudanese President Salva Kiir Mayardit paid a visit to China National Petroleum Corporation Headquarters and had talks with Wang Yilin about further deepening oil and gas cooperation. A memorandum was also signed after talks to boost existing production and consider acquisitions of new acreage. The high profile visit signifies the closeness of South Sudan and China. Mombasa-Nairobi link when  it will be joined with Juba in South Sudan through branch line then it will open an alternate route for Chinese companies and South-Sudan for trade and export of Oil. Moreover, cost is critical in the production of goods and to remain competitive in the globalized economy. Fuel is one such factor that has cascading effect on the entire supply chain right from manufacturing to retail. In September, 2018 Sudan Ministry of Petroleum signed an agreement with three oil companies operating in Sudan and South Sudan to pay a transit fees of $14 per barrel. One of the companies that signed the agreement is China National Petroleum Corporation. In addition to it, if oil is shipped through Sudan, Chinese companies will also have to pay fees for marine terminal usage. Therefore, opening up of an alternate supply route using Mombasa port and railway link will give an edge to China. Therefore, Mombasa is a strategically important port for China as it will be a gateway to South Sudan.  

S

Straight Talk

 

MARKETS AND CRUDE PRICES CRASHING; A NEW ROI OPPORTUNITY

IMPROVING ROI THROUGH TREND ANALYSIS is a hallmark of prudent financial analysts and CEO's, often leading to long, prosperous tenures. With rising sentiments surrounding the negative impacts of fossil fuels, and a reluctance of oil, gas and coal producers to recognize, let alone embrace global trends and zero emission synfuel technologies that could provide substantial market lead and much higher earnings for less cost, few if any industry CEO's today will still hold their title in 2-5 years, as only those firms offering fuel products which align with public sentimentl offered at a much lower price and cater to a changing political landscape will remain profitable.

CM

ParisPlans

 

Reactions to Delaware Basin news shows misunderstanding of petroleum economics (or the end of OPEC) by Dr. Daniel Fine

The full article is here-> https://www.daily-times.com/story/money/industries/oil-gas/2018/12/18/delaware-basin-news-reveals-public-misunderstanding-oil-industry-economics/2282224002/ "This writer has warned that world oil demand is sluggish and imprecise with only references to legacy guesswork that the developing world plus China demand will support prices long term or forever. Yet, world oil consumption has increased only 5 percent in the last 10 years.   OPEC, with Saudi Arabia as its leader, has expired as the world administrator of the price of crude oil. At its December meeting in Austria, Qatar quit after nearly 70 years and announced concentration in LNG production and world export as the existing market leader. OPEC emerged with a serious factional split between OPEC original and OPEC with Russia. There would have been no agreement without Russia and its old Russian Federation members as producers. Moscow is the new world oil price-setter indirectly while OPEC Original becomes a collaborator in cartel for now. Simply put, Saudi Arabia no longer is the “residual supplier” alone. The production roll-back of 1.2 barrels per day by both “OPEC” is not enough for “balance” supply and demand for world crude oil.  It is being tested daily by commodity traders. In a briefing to New Mexico independent and small producers before the meeting in Austria, this writer warned that 1.7 million b/d was needed for balancing stabilization. Without that size of a production and export reduction, the average price of WTI oil in 2019 will average $50 per barrel. Nearing 12 million b/d and over the Permian producers voluntarily will be required by this price to revise capital spending and place production into DUC (non-completions) and storage. There is doubt that the export of tight or shale oil would continue if the Brent price falls lower and loses its premium over WTI. A net cutback of Permian between 500,000 to 750,00 b/d should be a non-OPEC response to an oil glut even more serious than 2014. Saudi Arabia is untouched as an American strategic ally in confronting Iran in the Middle East as a hegemonic threat."

RB

bluewill

North Dakota – update through October 2018

These interactive presentations contain the latest oil & gas production data from all 14,162 horizontal wells in North Dakota that started production since 2005, through October. Visit ShaleProfile blog to explore the full interactive dashboards Oil production in North Dakota climbed to 1,392 kbo/d in October, a month-on-month increase of more than 2%, and again a new record for the state. In the first 10 months this year 1,045 wells were brought online, which was more than in each of the two years before.   The 2nd tab (“Well quality”), shows that recent wells are performing slightly better than those from 2017, which recovered on average 160 thousand barrels of oil in the first year on production. In the “Well status” tab you can find the status of all these wells. By selecting the status ‘First flow’, you’ll find that 112 wells started producing in October (vs. 153 in September).   All leading operators have grown production in 2018 (“Top operators” tab). ConocoPhillips has almost taken over the 2nd spot from Whiting.   The ‘Advanced Insights’ presentation is displayed below:   This “Ultimate recovery” overview shows how all these horizontal wells are heading towards their ultimate recovery, with wells grouped by the quarter in which production started. It reveals that the wells that started in Q3 2017, marked by the dark green curve at the top, have shown so far the best performance, although the wells from 2018 are closely tracking a similar path.   The 2nd tab (‘Cumulative production ranking’), ranks all wells (from unconventional reservoirs) by cumulative production. The top 2 wells have produced each more than 1.6 million barrels of oil, and each of them still produces at a decent rate (>100 bo/d). Five more wells have also produced more than 1 million barrels of oil so far. The median well has produced a little below 200 thousand barrels of oil.   The ‘Productivity over time’ dashboard shows clearly how well productivity (as measured by the cumulative oil or gas production in the first x months), has increased in the past few years. We have a similar dashboard in our online analytics service, which allows you to normalize production, and which also shows the trends in well design (lateral length & proppant loading). It offers the possibility to quickly compare the performance of operators over time, in relation with how each has changed its completion practices. We will have a new post on the Marcellus just after Christmas. In our chat on enelyst, tomorrow (Dec 18th) at 10:30 am EST, we will take a closer look at the Bakken. If you are not yet an ign up for free at: www.enelyst.com, using the code: “Shale18”.enelyst member, you can s For these presentations, I used data gathered from the following sources: DMR of North Dakota. These presentations only show the production from horizontal wells; a small amount (about 30 kbo/d)  is produced from conventional vertical wells. FracFocus.org   Visit our blog to read the full post and use the interactive dashboards to gain more insight http://bit.ly/2SRAuN9   Follow us on Social Media: Twitter: @ShaleProfile
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shaleprofile

US - update through August 2018

This interactive presentation contains the latest oil & gas production data from 96,273 horizontal wells in 10 US states, through August. Visit ShaleProfile blog to explore the full interactive dashboards Cumulative oil and gas production from these wells reached 9.5 Gbo and 104 Tcf. Ohio and West Virginia are deselected in most dashboards, as they have a greater reporting lag. Oil production from horizontal wells in these states grew by almost 2 million bo/d in the 2 years through August. This growth rate was similar as in the boom years of 2013-14. The Permian was responsible for most of this gain, which you’ll see if you show the production data by ‘Basin’ (using the ‘Show production by’ selection). Natural gas production has been setting new records as well during those 2 years and was above 47 Bcf/d in the basins we cover.   The steady increases in well productivity are shown in the ‘Well status’ tab, where all the oily basins are preselected. The horizontal wells that started in 2018 are so far closely tracking the performance of the ones from 2017.   In the final tab you will find the production histories and location of the largest shale operators. We’ve made a change in this dashboard; now the operators are ranked by their total production in the past 12 months (and not by their total historical production). This makes especially a big difference in the Permian, where several operators have recently increased production at a rapid rate. The ‘Advanced Insights’ presentation is displayed below:   This “Ultimate recovery” overview shows the relationship between production rates and cumulative production over time. The oil basins are preselected, and wells are grouped by the quarter in which production started. Since about 2010 wells have been tracking ever larger ultimate recoveries. The ~1,300 horizontal wells that started in Q4 of 2016 appear so far among the best performers; they have recovered on average 160 thousand barrels of oil and are now at a production rate of ~110 bo/d (from a peak rate of 570 bo/d). These are of course averages, and there are major differences between basins, operators and formations. Major factors behind the changes in well performance are the increases in lateral lengths and the larger frac jobs. In our online analytics service, it is possible to normalize for these factors. Feel free to request a demo, in which we will discuss your interests, or 10-day trial. We sometimes get the question about what we do with wells when they stop producing. In these cases we keep adding 0 production records, to make sure that wells don’t suddenly drop out of the equations, which would lead to a survivorship bias. You can verify this, as the exact well count is shown in the tooltips that appear above the production profiles (this is also represented in the thickness of the curves). Tomorrow at 9:30am EST we will again host a show at enelyst, in which we’ll take a closer look at the Niobrara basin. Join us in the ShaleProfile channel.   Early next week I will have a new post on North Dakota, which will release October production data by the end of this week. Production data is subject to revisions. For these presentations, I used data gathered from the sources listed below. FracFocus.org Colorado Oil & Gas Conservation Commission Louisiana Department of Natural Resources. Similar as in Texas, lease/unit production is allocated over wells in order to estimate their individual production histories. Montana Board of Oil and Gas New Mexico Oil Conservation Commission North Dakota Department of Natural Resources Ohio Department of Natural Resources Pennsylvania Department of Environmental Protection Texas Railroad Commission. Individual well production is estimated through the allocation of lease production data over the wells in a lease, and from pending lease production data. West Virginia Department of Environmental Protection West Virginia Geological & Economical Survey Wyoming Oil & Gas Conservation Commission   Visit our blog to read the full post and use the interactive dashboards to gain more insight http://bit.ly/2EbfM6U   Follow us on Social Media: Twitter: @ShaleProfile
Linkedin: ShaleProfile
Facebook: ShaleProfile

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shaleprofile

OPEC in crisis

We where supposed to have a deal on Thursday with OPEC so what happened? If you found a good deal on a house, would you delay the closing? You would if you saw some problems with the deal. Well what kinds of problems do we have with OPEC cutting productions and why wasn't it made today, after all the whole world is waiting. For the prices to stop going into a free fall and hit my $34 target, they need to cut production, Saudi by about 2 Mill barrels and Russia by 300,000 barrels, or at least 200,000 barrels. Well Russia did not have an answer today? Why? Well lets see where Russia Oil fields are?  Well this looks like a very cold place, if im not mistaken it gets to -70 Celsius in the winter. Ok so whats the problem? If you live in Northern Canada, you know you need to not turn off your heat in the winter to your pipes wont freeze. Well guess what, Russia won't be able to cut production in the winter, and it will need to wait until temps are above freezing, maybe March / April 2019.  So that means Russia wont be able to cut, so why should the Saudis cut, so they will cut im comparison with Russias cuts, which wont be enough to stop the fall of Crude Prices.

JJ

Top Oil Trader

Why OPEC has little effect

The fact that Qatar will leave next month, will be a blow for OPEC. This will weaken them in their ability to enforce production cuts from all its members. Lets also remember US is investigating OPEC for price manipulation. Russia is not part of OPEC and can refuse to cut production. Shale oil is getting more efficient, selling oil at $10 under par. In Canada its now $43 under par. Bottom line is, oil prices are in a free fall. 

JJ

Top Oil Trader

Permian – update through August 2018

This interactive presentation contains the latest oil & gas production data from all 17,650 horizontal wells in the Permian (Texas & New Mexico) that started producing since 2008/2009, through August. Visit ShaleProfile blog to explore the full interactive dashboards Oil production in the Permian from horizontal wells has continued to rise at an astonishing pace, adding about 1 million bo/d in production capacity in the 12 months through August, to about 2.7 million bo/d (with upward revisions coming). The main driver behind this growth is the high level of completion activity; so far more than 2,800 horizontal wells have been completed this year, double the level of just 2 years ago, and 40% higher than last year. As shown by the blue area in August, those wells that started so far this year were already contributing to more than half of the total output in that month.   Well productivity has not changed by much in the past 2 years, as shown in the ‘Well quality’ tab. The wells that started in 2018 are so far tracking a recovery slightly ahead of the average 2016 well, which is on a path to recover about 200 thousand barrels of oil in the first 30 months on production (and hitting that level with a flow rate of ~100 bo/d).   Concho finalized the acquisition of RSP Permian in July, and is now the leading unconventional oil producer in the Permian (see ‘Top operators’), just ahead of Pioneer Natural Resources.   The ‘Advanced Insights’ presentation is displayed below:   This “Ultimate recovery” overview shows the average production rate for these wells, plotted against their cumulative recovery. Wells are grouped by the quarter in which production started. The improvements in recovery trajectories over the past 8 years are clearly visible here, driven by major changes in well design (longer laterals, bigger frac jobs). However, since early 2016 these trajectories have not shown further clear gains, even though younger wells are still peaking at a higher rate than before. Later today (04.12.'18) we will have a new show at enelyst (live chat combined with images), where we will take a closer look at the Eagle Ford, on which we reported last week. The show will be available here in the enelyst ShaleProfile Briefings channel. If you are not an enelyst member yet, you can sign up for free at enelyst.com.   Early next week I will have a post on all 10 covered states in the US. If you are considering to subscribe to our data or analytics service, don’t wait too long! Starting from January 1st, we will raise our prices with a few percent. Request a trial or a demo here, or contact us. Production data is subject to revisions. Note that a significant portion of production in the Permian comes from vertical wells and/or wells that started production before 2008, which are excluded from these presentations. For these presentations, I used data gathered from the following sources: Texas RRC. Oil production is estimated for individual wells, based on a number of sources, such as lease & pending production data, well completion & inactivity reports, regular well tests and oil proration data. OCD in New Mexico. Individual well production data is provided. FracFocus.org   Visit our blog to read the full post and use the interactive dashboards to gain more insight http://bit.ly/2EeYuH2   Follow us on Social Media: Twitter: @ShaleProfile
Linkedin: ShaleProfile
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shaleprofile

Quatar leaves OPEC

There has been lots of rift between the Saudis and Qatar, for quite some time. Saudi Arabia is accusing Qatar of financing terrorism. The Saudis are trying to give Qatar lots of problems, and Qatar fought back, by damaging OPEC and leaving. This will be the beginning of the unraveling of OPEC as I predict more nations to leave OPEC. This will also give OPEC less control of oil prices. Therefore any production cuts from OPEC in the future could soon become meaningless.

JJ

Top Oil Trader

 

Analysis: Trump and Saudi collision on oil, and Bingaman’s return to Santa Fe

The full article is here-> https://www.daily-times.com/story/money/industries/oil-gas/2018/11/25/analysis-trump-and-saudi-collision-oil-bingamans-return-santa-fe/2015081002/ "In an earlier column, readers overseas benefited from this writer’s forecast that crude oil prices would fall dramatically because most commodity traders got it wrong. Simply, this column’s analysis was the buying of oil assumed a shortage would result once the sanctions against Iran would be activated the first week of November.    President Trump wanted lower oil prices with OPEC and Saudi Arabia pumping more. Two weeks ago, a call from the Middle East confirmed readers of the column had followed the analysis in the Energy Magazine and sold Brent oil — and profited.   Oil has slumped under $60 as the delusion of a shortage vanished. In the November issue column, this writer made a call: the oil price would reach $50 as a low. There is no change in that forecast. The price in the commodity market for WTI crude would touch in the very high $40 range before the Saudi-led production cut-back is realized. Why? Again, too much capacity to produce too much oil for demand. What's the impact on SW oil? Oil demand without commodity traders’ bets on the sanctions against Iranian oil production and export contradicts flagging demand. Some Southwest shale producers, faced with discounts on domestic sales, are exporting oil to world markets and capturing the higher Brent price or differential between the WTI priced Midland domestic and the Brent price for the World.     But this would shift Southwest tight oil into a world market where such supply also chases weaker demand. This switches U.S. oil into world oil as exports and diverts it from going into U.S. storage. Unlike the last three price sell-offs Saudi Arabia, speaking for OPEC, is strangely silent on calling on non-OPEC producers join it in lowering production or “balancing” the market.      Quite the opposite. Led by shale producers in the Delaware (New Mexico) Basin in the Permian complex, United State production approaches 12 million barrels per day, a historic high and number one position against the Middle East and Russia."

RB

bluewill

Eagle Ford - update through August 2018

This interactive presentation contains the latest oil & gas production data from all 21,540 horizontal wells in the Eagle Ford region, that started producing since 2008, through August. Visit ShaleProfile blog to explore the full interactive dashboards Since the low point two years ago, oil production in the Eagle Ford has kept growing. I expect that after revisions August production will eventually come in at around 1.3 million bo/d (~100 kbo/d higher than shown now).   Natural gas production follows a very similar pattern. If you switch ‘Product’ to gas, you’ll find that in 2018 total gas production was just below 6 Bcf/d. The underlying decline is clearly visible in this graph; you can see that the horizontal wells from before 2015 peaked at over 1.6 million bo/d in Dec 2014, and that the same group produced just 0.3 million bo/d in August.   The main reason for the recent increase in oil production is not higher well productivity, as this has not significantly changed in the past 2 years (see ‘Well quality’). But about 5 wells have been completed every day in 2017 & 2018, on average, versus just 4 in 2016.   The ‘Advanced Insights’ presentation is displayed below: In this “Ultimate Recovery” overview, the relationship between production rates and cumulative production is revealed. Wells are grouped by the year in which production started. Declines here are steeper than in the Permian or the Bakken, and that means that a greater part of the oil EUR is recovered in the first year on production (about half). I wanted to have a closer look at the well performance of the two leading operators, EOG & ConocoPhillips. Here you find this comparison, for horizontal wells that started between 2014 & 2017, taken from our ShaleProfile Analytics service. For each operator & year combination, you can see the performance curve on the right plot. Striking here is the difference in well behavior. EOGs wells decline in a fairly straight line from the peak, while the wells operated by ConocoPhillips are able to maintain a higher flow rate for several months, before they display a steepening of the decline. Early next week we will have a post on the Permian again.   Production data is subject to revisions, especially for the last few months. For this presentation, I used data gathered from the following sources: Texas RRC. Production data is provided on lease level. Individual well production data is estimated from a range of data sources, including regular well tests, and pending data reports. FracFocus.org   Visit our blog to read the full post and use the interactive dashboards to gain more insight http://bit.ly/2Q2eRwV   Follow us on Social Media: Twitter: @ShaleProfile
Linkedin: ShaleProfile
Facebook: ShaleProfile  

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shaleprofile

offshore wind energy market Offshore Wind Energy Market’s Cumulative Offshore capacity Is Expected To Reach to 49,931.6 MW By 2025

According to a new market report published by Credence Research “Global Offshore Wind Energy Market , by foundation type (Monopile, Jacket, Tripod, Floating), by Water Depth (shallow water [up to 29m deep], transient water [30-60m deep] and deep water [60m and above]) and by Geography (North America, Europe, Asia Pacific and Rest of the World) - Growth, Future Prospects and Competitive Analysis, 2017 – 2025,” the offshore wind energy market volume is expected to reach to 49,931.6 MW by 2025 Browse the full offshore wind energy market, by foundation type (Monopile, Jacket, Tripod, Floating), by Water Depth (shallow water [up to 29m deep], transient water [30-60m deep] and deep water [60m and above]) and by Geography (North America, Europe, Asia Pacific and Rest of the World) – Market Growth, Future Prospects and Competitive Analysis, 2017 – 2025 Market Insights Offshore wind energy (offshore wind power) is the conversion of wind’s kinetic energy into electrical energy. Uniform and high speeds of wind can be harnessed in offshore environment since it accounts to nil obstruction to wind force. Multiple windmills together constitute to a wind farm. These farms are constructed in the water bodies usually oceans to harvest the energy of wind and convert it into electrical energy. Browse the full report at https://www.credenceresearch.com/report/offshore-wind-energy-market The offshore wind installations reduces the impact on real estate as in onshore installations. Moreover, wind speed is uniform and consistent in offshore installations, which increases the efficiency of electricity generation. Thus, the offshore wind energy is highly attractive and more promising in terms of power generation and grid connections. Some of the restraining factors of offshore wind installations are wind turbines are exposed to high humidity and salt contents, which affects service life of components due to corrosion, oxidation and increased repair and maintenance costs. In general, the offshore installation costs are much higher than onshore.  The repair maintenance and overhauling operations are also high cost and time consuming as it requires expensive marine operations involvement and are comparatively dangerous. The offshore wind farms operate at high speeds compared to onshore wind farms, hence offshore turbines are more susceptible to high rate of wear and tear, maintenance and repair of moving parts. In the early 2017, Denmark has come up with new recycling process of offshore wind turbine blades, made up of fiberglass. When the wind turbine is de-commissioned, the blades may fall off to the landfill area where it may take many years to decompose. The blades can now be recycled and applied as sound barriers of vehicular traffic along major roads. The key players, developers, suppliers and service providers are Siemens-Gamesa, MHI Vestas Wind Systems A/S, DONG Energy, VattenFall, E.on, GE Wind, Sinovel Wind Group Co. Ltd., Nordex S.E, China Ming Yang Wind Power Group Ltd, Alstom, Senvion Ltd., Clipper Wind power, and DOOSAN Heavy Industry & Construction. Key Trends: Rising investor confidence in the offshore wind energy market. More financial institutions and Governmental agencies actively investing in the market for development of offshore wind farms. Deployment of 8MW and above wind turbine in European and Chinese farms and its introduction in the respective countries for proposed offshore wind power projects  

JP

johnsonpaul

Niobrara (CO & WY) - update through September 2018

These interactive presentations contain the latest oil & gas production data, from all 9,508 horizontal wells that started production in Colorado and Wyoming since 2009/2010, through September. Since the last post, we’ve also added several other regions in these 2 states, and they are included here. Visit ShaleProfile blog to explore the full interactive dashboards In August a new record was set, at over 0.5 million bo/d. After revisions are in I believe September will show a higher level again. Weld County produces about 75% of this output (group production by ‘County’ to see this).   Decline rates are fairly high, and most wells are at or below 20 bo/d after 4 years on production, as you’ll see in the ‘Well quality’ tab. In the ‘Well status’ tab the statuses are shown for all these wells. After selecting only ‘First flow’, you’ll note that the number of wells that started production in July and August (>160) was almost back to the record levels in 2014.   The final tab shows the leading operators and the location of their operated wells. Extraction Oil & Gas tripled its output in the past 1.5 years, and is now the number 3.   The ‘Advanced Insights’ presentation is displayed below: In this “Ultimate Recovery” graph, the average cumulative production of all these horizontal wells is plotted against the production rate. Wells are grouped by the quarter in which production started. A major jump in average well productivity can be seen near the end of 2016, marked by the pink and red curves at the top, after which it has slightly fallen.   The 2nd tab ranks all wells by their cumulative production. The best three horizontal wells since 2009 have now produced more than 0.5 million barrels of oil, and they are all located in Campbell County (WY).   Last week we published a post on gas production in Pennsylvania. Tomorrow (Tuesday), at 10:30 EST, we’ll go over that in more detail in our show at enelyst: enelyst ShaleProfile Briefings channel. If you are not an enelyst member yet, you can sign up for free at www.enelyst.com, using the code: “Shale18” We have upgraded our data release procedure, and are now able to share on a weekly basis our database with ShaleProfile Data subscribers. More info can be found here. Later this week we will have an update on the Eagle Ford, followed by the Permian early next week. Production data is subject to revisions. For this presentation, I used data gathered from the following sources: Colorado Oil & Gas Conservation Commission Wyoming Oil & Gas Conservation Commission FracFocus.org   Visit our blog to read the full post and use the interactive dashboards to gain more insight http://bit.ly/2PWT8pP   Follow us on Social Media: Twitter: @ShaleProfile
Linkedin: ShaleProfile
Facebook: ShaleProfile  

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shaleprofile

motor gasoline market Motor Gasoline Market Is Expected To Each US$ 1,792.4 Bn by 2024

The latest market report published by Credence Research, Inc. “Global Motor Gasoline Market, By Geography- Growth, Future Prospects and Competitive Analysis, 2016 – 2024” the global Motor Gasoline market was valued at US$ 1,134.1 Bn in 2016, and is expected to each US$ 1,792.4 Bn by 2024, expanding at a CAGR of 5.9% from 2016 to 2024. Browse the full report at https://www.credenceresearch.com/report/motor-gasoline-market Market Insights Global Motor Gasoline market is projected to witness substantial growth over the forecast period. Rapid growth in disposable income of middle class especially in emerging economies of Asia Pacific is expected to fuel the demand for automobiles which in turn is projected to drive the demand for motor gasoline over the forecast period. In 2015, sales of passenger cars reached to 73.9 Mn vehicles out of which sales of passenger vehicles in China and Japan was 21.15 Mn vehicles and 4.22 Mn vehicles respectively. Followed by it, U.S. stood at second position with annual sales of 7.57 Mn vehicles annually. Robust growth in sales of passenger vehicles is projected to fuel the demand for the motor gasoline over the forecast period. However, growing use of alternatives such as LPG, Diesel and CNG as fuels coupled with increasing initiatives of government to promote use renewable fuels is anticipated to restrain the demand for global motor gasoline market during the forecast period (2016-2024). By geography, North America was the largest region in global motor gasoline market in 2015. The growth in the region is fueled by increasing sales of automobiles in the regions especially in U.S. Followed by it, Asia Pacific is anticipated to be the second largest and fastest growing region in global motor gasoline market. China, Japan and India is anticipated to drive the demand for the motor gasoline in the region over the forecast period (2016-2024). Considering the competition, the global motor gasoline market is expected to witness a significant rise in investment in capacity expansion for the production and supply of gasoline to cater the increasing demand for motor gasoline. Further, market has witnessed strategic mergers and collaborations among motor gasoline regional and global players. Such growth strategies are focused on increasing their market penetration in key consuming economies. Download Sample Here: https://www.credenceresearch.com/sample-request/58367 For the purpose of this study, the global motor gasoline market is categorized into: North America Europe Asia Pacific Latin America (LATAM) Middle East and Africa (MEA)  

JP

johnsonpaul

oil storage market size Oil Storage Market Size, Share, Growth, Future Prospects, Competitive Analysis and Forecast 2018 To 2026

The latest report from Credence Research on “Oil Storage Market” market offers comprehensive understanding on market sizes and trends, competitive analysis, and market forecast from 2018 to 2026. Credence Research report helps to discover future business opportunities for stakeholders in this sector by highlighting different aspects such as potential revenues streams, market drivers, opportunities, challenges, issues, and events impacting the “Oil Storage Market” market. “Oil Storage Market” market report covers detailed analysis and forecast for “Oil Storage Market” market segmentation, leading continents along with major countries, and profiles of major companies operating in “Oil Storage Market” market. Browse Full Report with Toc: https://www.credenceresearch.com/report/oil-storage-market Credence Research employs extensive research methodology to derive market size and forecast. Detailed secondary research has been conducted by exploring “Oil Storage Market” related sources, directories, and databases to grasp the market information and dynamics, followed by primary interviews with industry experts, and subject matter expert’s input to further validate the information sourced. Market size estimation involves triangulation of the data obtained from various approaches such as bottom-up, top-down, demand-side, and supply-side. The report studies different segments of “Oil Storage Market” market and provides both, qualitative and quantitative analysis along with competitive landscape, profiling of key players and their preferred development strategies that helps to formulate competitive market strategies and take informed decisions. How this report is useful? The “Oil Storage Market” report will reinforce the strategic decision-making with authentic and reliable market data. It identifies the key competitors operating in the market and their positioning and strategies. The study reveals the new and upcoming technological trends to give you an edge over your competitors. Market data, dynamics, and industry model covered in the report offers clarity on different markets across the value chain and support the decision making regarding entering and exiting the industries. The study also highlights the investment opportunities and revenue pockets present in the market. Download Free Sample Here: https://www.credenceresearch.com/sample-request/58146 Who should buy this report? ·      Stakeholders across the “Oil Storage Market” market value chain. ·      Business development managers ·      CEO’s ·      COO’s ·      Marketing managers ·      Technologists ·      Suppliers ·      Investors ·      Banks ·      Government agencies Major highlights of the study ·      Global “Oil Storage Market” market outlook ·         Classification of the “Oil Storage Market” market based on their major segmentation and Geography ·         Market segments analysis with respect to geographies and their respective countries ·      Industry analysis such as SWOT analysis, Value Chain Analysis, and Porter’s Five Force model for “Oil Storage Market” market ·      Analysis of the key drivers, restraints, and future prospects at global and regional level ·      Market positioning of key players ·      Profiles and competitive dashboard of the leading 10 companies in 2018 at a global level By Reserve Type Commercial Petroleum Reserve Strategic Petroleum Reserve By Geography North America Europe Asia Pacific Latin America Middle-East & Africa (MEA) Key players across the global defoamer’s market value chain are: Oiltanking GmbH, Royal Vopak N.V, Horizon Terminals Ltd and Magellan Midstream Partners L.P., others.  

JP

johnsonpaul

naphtha market Naphtha Market Size, Share Is Expected To Reach US$ 230.9 Bn by 2030

The latest market report published by Credence Research, Inc. “Naphtha Market, By Product Type and By Geography- Growth, Future Prospects and Competitive Analysis, 2016 – 2030,” the global naphtha market was valued at US$ 102.6 Bn in 2016, and is expected to reach US$ 230.9 Bn by 2030, expanding at a CAGR of 5.97% from 2016 to 2030. Click Here for Full Report at https://www.credenceresearch.com/report/naptha-market Market Insights Global naphtha market is projected to witness significant growth over the forecast period. Growing demand for naphtha as a feedstock in petrochemical industry is projected to drive the demand for naphtha over the forecast period. Increasing use of plastic products fueling the demand for the polypropylene and polyethylene which in turn is driving the demand for naphtha used as a feedstock for the production olefins and aromatics using in production of paints and coatings. Further, naphtha also finds application in blending with gasoline. Growing demand for gasoline is anticipated to augment the growth of global naphtha market. Moreover, recent technological advancement such as development of advance furnace materials, advanced distillation column and alternative technologies such as hydro- pyrolysis of naphtha and catalytic cracking of naphtha saves approximately 10% of the energy which in turn reduces the production cost. Thus, making naphtha the preferred feedstock for the end use applications. Growing chemical industry especially in Asia Pacific is projected to drive the global naphtha market during the forecast period (2016-2030). However, growing use of alternatives such as LPG for the production of propane and butane are expected to restrain the growth of global naphtha market during the forecast period (2016-2030). By Product type, heavy naphtha segment was the most dominant segment in 2015 and anticipated to continue its dominance of over the forecast period. The segment is projected to witness stable growth during the forecast period. Light naphtha segment is expected to be the fastest growing segment during the forecast period. Growing use of light naphtha in petrochemical steam crackers is anticipated to fuel the demand over the forecast period (2016-2030). By application, chemical segment was observed to be the largest segment in 2015 in global naphtha market. Increasing use of naphtha as a feedstock for the production of materials such as polyethylene and polypropylene in petrochemical industry is projected to fuel the growth of naphtha over the forecast period (2016-2030). Considering the competition, the global naphtha market is expected to witness a significant rise in investment in capacity expansion for the production and supply of naphtha. Further, market has witnessed strategic mergers and collaborations among naphtha regional and global players. Such growth strategies are focused on increasing their market penetration in key consuming economies. Download Free Sample Request: https://www.credenceresearch.com/sample-request/58350 By Product Heavy Naphtha Light Naphtha By Application Chemical Energy/Fuels Others By Grography North America Europe Asia Pacific Latin America (LATAM) Middle East and Africa (MEA)

JP

johnsonpaul