tu aurais des sources ?
quand je regarde ici http://phx.corporate-ir.net/phoenix.zht ... portsother
il y avait 735 puits sur les 7 principaux sites de production de pétrole de Schiste US il y a un an,
contre 764 puits aujourd'hui.
tu aurais des sources ?
https://oilprice.com/Energy/Crude-Oil/R ... ecord.htmlRed Hot Permian Set To Jolt U.S. Shale Output To New Record
By Tsvetana Paraskova - Apr 16, 2019
Crude oil production from the seven key shale regions in the United States is expected to increase by 80,000 bpd from April to hit a record 8.46 million bpd in May, with the Permian accounting for half of the monthly growth, the EIA said in its latest Drilling Productivity Report.
Crude oil production from the seven major shale producing regions is set to increase from 8.38 million bpd this month to 8.46 million bpd next month. The fastest-growing region, the Permian, is expected to see its crude oil production jump by 42,000 bpd from April to hit a record high of 4.136 million bpd in May, according to the EIA estimates—a figure that would place the US hotspot as OPEC’s third-largest producer behind only Saudi Arabia (9.79 bpd) and Iraq (4.52 bpd).
In the report forecasting production in May, the EIA sees the Niobrara region adding 22,000 bpd to reach oil production of 764,000 bpd in May—this would be the second-largest growth after the one in the Permian. The Bakken, the Eagle Ford, and Appalachia regions are also expected to see higher production in May compared to April, while Anadarko region’s crude oil production is forecast to drop slightly next month.
https://www.spe.org/en/jpt/jpt-article-detail/?art=5419Chinese-Owned Operator Claims Longest Permian Lateral
24 April 2019
Chinese-owned, Houston-based Surge Energy reported that its subsidiary, Moss Creek Resources, drilled the Medusa Unit C 28-09 3AH well in the West Texas Permian Basin to a TMD of 24,592 ft, with a total horizontal displacement of 17,935 ft, or 3.4 miles.
Latshaw Drilling & Exploration's Rig 10 drilled the well, which stayed 100% in zone of the Wolfcamp A formation, over 18 days from surface to total depth utilizing conventional mud motor and measurement-while-drilling technology. It is the longest known lateral in the Permian based on the IHS and Drillinginfo databases, Surge said.
The well is expected to be completed and brought online later in the year.
https://oilprice.com/Energy/Energy-Gene ... rmian.htmlBig Oil’s Biggest Weapon In The Permian
By Tsvetana Paraskova - Apr 28, 2019
While European oil supermajors are yielding to investor pressure to set emission reduction targets and announcing investments in renewables and EV charging networks, U.S. majors ExxonMobil and Chevron are doubling down on oil production on their home turf, turning the ‘shale game’ into a ‘scale game’, as Chevron’s CEO Michael Wirth has recently said.
The two biggest U.S. oil firms aim to boost significantly their respective production from the most prolific U.S. basin, the Permian, which now pumps more than 4 million bpd of crude oil.
Both Exxon and Chevron hold vast acreage positions in the basin, and both have the financial resources to invest in ramping up shale production even through various oil price cycles, even at oil prices at which smaller independent drillers struggle to break even and scale back drilling and capital spending.
The shorter-cycle shale production yields returns in two-three years, compared to many years of lag time from discovery to development to start-up of complex offshore oil projects, for example.
While Exxon and Chevron are not giving up on their most promising conventional oil projects outside the U.S., their common key priority by the middle of the next decade will be the Permian. And in order to achieve their ambitious growth targets, the U.S. supermajors rely on innovation—not only innovation in drilling, but also digital innovation and transformation with increased use of various AI technology, cloud computing, automation, and data analytics.
Chevron and ExxonMobil, for example, work with Microsoft to boost efficiencies and profits
Chevron signed in 2017 a seven-year partnership with Microsoft, under which the tech giant is Chevron’s primary cloud provider and the companies are working on speeding up the application of analytics and the Internet of Things (IoT).
Earlier this year, Exxon struck a digital partnership with Microsoft to use cloud technology to increase oil production and profitability in the Permian. According to Exxon, the partnership will make its Permian operations the largest-ever oil and gas acreage to use cloud technology. Cloud technology application is expected to generate billions of U.S. dollars in net cash flow for Exxon over the next decade, as data analysis and operational efficiencies improve. The partnership also has the potential to increase Exxon’s production in the Permian by 50,000 oil-equivalent barrels a day by 2025, the U.S. supermajor says.
Last month, Exxon and Chevron announced increased targets for their Permian production. Chevron now sees its Permian unconventional net oil-equivalent production rising to 600,000 bpd by the end of 2020, and to 900,000 bpd by the end of 2023. In 2018, Chevron’s annual production in the Permian was 310,000 bpd, up by 71 percent on the year.
Chevron boasts a “unique position” in the Permian “characterized by long-held acreage, zero-to-low royalty on more than 80 percent of our land position, and minimal drilling commitments,” said Jay Johnson, executive vice president, upstream. These factors, combined with the use of new technologies, are driving higher returns and stronger cash flows, according to Johnson.
Similarly, Exxon also revised up its Permian growth plans to produce more than 1 million oil-equivalent barrels per day by as early as 2024, which would be an increase of almost 80 percent.
The shale game is now a ‘scale game’, Chevron’s Wirth told CNBC in March after the company announced its latest Permian growth targets.
“The big thing that I think has changed is the shale game has become a scale game, and so people that can do things at large scale and bring the capabilities to bear that a company like Chevron has are the ones that really can take this to the next level,” Wirth told CNBC.
While independent exploration and production firms are much more sensitive to oil price trends in their drilling plans, the supermajors are bringing in scale and technological innovation to the shale game to squeeze as much profits from the Permian as possible.
Chevron’s agreement to buy Anadarko and Occidental Petroleum’s offer two weeks later to buy Anadarko at a higher price than the one Anadarko had accepted from Chevron highlight “a larger scale pivot in supermajors strategy to short cycle shale investments,” Tortoise, which invests in energy assets, said in a recent update.
“With strong balance sheets, stable multi-year investment programs and the ability to invest through production cycles, the expanding presence of supermajors in U.S. shale is positive for stable, visible longer term production growth,” said Tortoise, noting that it expects “more large acquisitions of independent U.S. E&Ps, particularly in the Permian basin, as the supermajors look to increase scale by blocking up significant chunks of acreage to support their growth plans in the future.”
By Tsvetana Paraskova for Oilprice.com
One of these logistical sticking points concerns the high volumes of diesel required to power hydraulic fracking rigs. “Electric frack enables the switch from diesel-driven to electrical-driven pumps powered by modular gas turbine generating units,” Simonelli told investors on this week’s call. “This alleviates several limiting factors for the operator and the pressure pumping company such as diesel truck logistics, excess gas handling, carbon emissions and the reliability of the pressure pumping operation.”
https://marcellusdrilling.com/2018/06/c ... ing-fleet/CNX Signs Deal with Evolution to Use 100% Electric Fracking Fleet
June 21, 2018
CNX Resources announced Tuesday that the company has signed a long-term contract with Evolution Well Services to use Evolution’s 100% natural gas-fueled electric pressure pumping equipment. That is, CNX will use electric fracking equipment, with the electricity generated by burning natural gas (instead of diesel). According to Evolution, their “next generation” equipment saves drillers “up to 95 percent on fuel costs.” Whoa! If that claim is true (we have no reason to disbelieve it), it certainly changes the economics of fracking. Using natgas to generate the electricity, instead of diesel, also has the benefit of cleaner air. And here’s the coolest part: The natural gas used to power the electric generator comes from other other CNX wells in the area, i.e. “field gas.” Look ma, no more endless truck deliveries of diesel fuel! Here’s the exciting news that CNX is a “first-mover” on this new technology…
en retombant sur cette stat, je me suis fait la reflexion que cette info reste une indication du potentiel de production.tita a écrit : ↑12 avr. 2019, 10:18Non, c'est juste que l'eia calcule des trucs farfelus. Dans le dpr, il y a un truc qui s'appelle "New-well oil production per rig". Sauf que le décompte des forages ne correspond pas à la mise en production de nouveaux puits (certains sont des DUC, drilled but uncompleted). Le décompte des DUC dans le bassin permien augmente énormément. Et il y a un décalage entre forages et
Ce qui n'est pas le cas d'Eagle Ford, où ça monte gentiment, et Bakken ou le décompte des DUC diminue.
On s'en rend compte si on regarde le "new-well oil production per rig" d'Eagle Ford, qui fait un pic mi-2016. C'est justement à ce moment que le nombre de DUC diminuait fortement... Ils mettaient en production plus de puits qu'ils n'en creusaient (rig count).
Perso, je ne comprends pas à quoi sert cette statistique... ça ne veut rien dire.
Exactement! Et c'est peut-être quelque chose qu'on va observer à la fin de l'année, vu qu'à mon humble avis ils vont connecter ces puits déjà forés et qu'on aura un taux de forage moins élevé que le taux de complétion. On verra bien!alain2908 a écrit : ↑09 mai 2019, 14:59en retombant sur cette stat, je me suis fait la reflexion que cette info reste une indication du potentiel de production.
Si ce ce que tu dis est juste. ca veut quand meme dire que dans le permien, on peut monter àune moyenne de 1 300 barrils/jour par puit alors qu'on est actuellement à 650 de moyenne du fait des puits non connecté.
https://www.spe.org/en/jpt/jpt-article-detail/?art=5354Looking for Fracturing Sand That Is Cheap and Local
Stephen Rassenfoss, JPT Emerging Technology Editor | 01 May 2019
Proppant buyers insist on the “lowest cost for an appropriate sand.” That assessment was offered by Hayden Gillespie, president and chief operating officer of Black Mountain Sand, one of the mining companies that has driven down sand prices by building sand mines within a couple of hours’ drive from where it is used.
Cheap sand is easy to find in the Permian Basin, where regional sand mines have glutted the market. Nearby suppliers have an unbeatable price advantage over distant mines, which not long ago produced most of the sand used for propping fractures.
Appropriate is harder to define. The rules are changing as customers try new mixes of sand size and find that production data does not support many of the old standards.
Rigs = appareils de forage de puits
https://www.rigzone.com/news/pioneer_cu ... 3-article/Pioneer Cuts Hundreds of Workers in Texas
by Valerie Jones|Rigzone Staff|Wednesday, May 22, 2019
Pioneer Natural Resources Co. has laid off 230 employees in Texas, according to local news outlets.
The layoffs, which The Dallas Morning News reported occurred Tuesday, affected 160 employees in the company’s Las Colinas office and 70 employees in its Permian office.
The cuts account for 25 percent of the Permian pure-play company’s workforce and are part of its corporate restructuring efforts to eliminate $100 million in general and administrative (G&A) costs.
“As a leader in the Permian Basin, we continue to take steps to reduce our cost structure. We ended last year by executing on strategic initiatives to materially reduce our drilling, completion and facilities capital. We are now taking action to reduce our corporate general and administrative costs,” Pioneer CEO Scott Sheffield said in the company’s first quarter financial and operating report.
Earlier this month, Pioneer asked one-third of its senior managers to retire.
Those affected in Tuesday’s layoffs will reportedly receive severance as well as job search assistance.