Hydraulic Fracturing

The world’s energy markets can’t rely on major growth in the Permian Basin U.S. shale patch to ease oil prices, according to Occidental Petroleum Corp. Chief Executive Officer Vicki Hollub.

The chorus is growing from America’s oil executives for President Joe Biden to throw the federal government’s weight behind an industry he once deliberately shunned: U.S. shale.

If the lights are going to stay on and homes are to keep warm in the harsh Ukrainian winter, Oleg Tolmachev is going to have to find a way to keep the gas flowing.

Inflation and brisk competition for the most-sophisticated drilling gear will hinder U.S. oil-supply expansion this year, according to shale giant EOG Resources Inc.

Oil executives tempted by the prospect of the highest crude prices in seven years are showing all the signs of abandoning pledges to hold the line on drilling budgets, Citigroup Inc. said.

Output in the U.S. shale patch is “re-booming” this year, with research and data analysis firm Lium LLC forecasting production will surge by more than 1 million barrels a day.

Chevron Corp. plans to increase Permian Basin production by about 10% this year from 2021 levels, among the biggest growth forecasts yet from any of America’s top shale producers.

Far Field Diversion Strategies - Presented by DiverterPlus: Advances in far field diverter materials and deployment strategies have enabled more consistency and greater efficacy in controlling fracture geometry to optimize production and/or minimize cross-well communication during hydraulic fracturing treatments. Employing simple laboratory techniques to determine the proper material composition can greatly improve the performance and economics of far field diverter with minimal impact on operations, while yielding measurable production improvements. Flowback Aids Case Study Unearths Hidden Benefits - Presented by Stepan Oilfield Solutions: The use of flowback aids in hydraulic fracturing is not a new topic, but previous case studies have focused primarily on the resultant increased production. Stepan Oilfield Solutions is taking it one step further. Join us as we discuss the results of a recent set of field trials with Raney Energy and also look at the holistic costs and benefits of using Stepan’s PETROSTEP® ME-2 Flowback Aid.

A coastal California county’s attempt to curb new oil and gas development suffered another blow when an appeals court upheld a ruling striking down a ban on new wells and hydraulic fracturing.

Low-carbon hydraulic fracturing is gaining traction across the U.S. But since it still extracts the very oil and gas that fossil-fuel critics want the world to stop consuming altogether, not everyone’s convinced.

In this webinar, industry experts Patrick Hayes and Dr. Sudiptya Banerjee will demonstrate the value of using chemical tracers as an essential technology throughout all phases of a reservoir E&P lifecycle with a focus on hydraulically stimulated wells. After outlining the different methods of tracer monitoring and guidelines for tracer selection, the webinar will explore the value proposition for using chemical tracer technology during and after exploration through a series of illustrative case histories. By the conclusion of this talk, attendees should understand how tracers can provide insight into their reservoir and production strategy.

US tight oil operators have for several months been depleting their inventory of drilled but uncompleted wells (DUCs) and, amid a slower drilling response, the number of ‘live’ DUCs in the country’s major oil regions slumped to 2,381 wells in June 2021, the lowest level since 2013, a Rystad Energy analysis reveals.

The American-made pump, built with quality and efficiency in mind, features a flow rate of more than 1000 gpm, making it suitable for demanding HDD projects.

Chesapeake Energy Corp., the once mighty shale explorer that exited bankruptcy earlier this year, is seeking to sell oil-producing assets in South Texas for as much as $2 billion, according people familiar with the plan.

Vitol Group is said to be near a purchase of Hunt Oil Co.’s Permian Basin oil wells in what would mark the biggest independent crude trader’s first major acquisition of U.S. production assets, according to people with knowledge of the matter.

iComplete™ is a fully integrated ecosystem that minimizes complexities using standardized equipment that can be set up for any unconventional well in the world. iComplete™ has 50 percent fewer components, 80 percent fewer connections, reduces OpEx costs by 30 percent, and drives further efficiencies through a digital interface, eliminating human intervention in the red zone. In this webcast, Graham Horn and John Eden will be sharing with the audience how TechnipFMC’s iComplete™ ecosystem is bringing the industry one step closer to a fully autonomous frac pad. This disruptive technology is increasing operation governance through reduced infrastructure, fewer personnel in the red zone and instance-based decision making – removing the manual process required to evaluate status and communicate, as well as the potential for human error.

Californian Governor Gavin Newsom will ban new hydraulic fracturing permits in the coming years as the state pushes to eliminate net greenhouse-gas emissions by 2045.

Kayrros has released measurements quantifying the total methane emissions across the Appalachian Basin. The findings, derived from satellite data and proprietary algorithms, place the Appalachian Basin ahead of the Permian as the biggest source of methane in the US and identify the primary sources behind its emissions.

The Railroad Commission of Texas issued a total of 798 original drilling permits in March 2021 compared to 744 in March 2020. The March 2021 total includes 682 permits to drill new oil or gas wells, 13 to re-enter plugged well bores, and 99 for re-completions of existing well bores.

The field test, completed on behalf of a major operator, was comprised of more than 300 operating hours with an average of more than 18 pumping hours per day, including the completion of 172 stimulation stages at rates up to 22 barrels per minute.

Today's modern fracturing fleets are expected to deliver the highest level of performance, productivity, efficiency and reliability. E&P's require a diversified fleet which can handle multiple pumping scenarios without having to change equipment or book separate specialized fleets, while also achieving emissions reduction targets driven by ESG goals/initiatives. CUDD Energy Services chose mtu’s 16V 4000 T95 3000HP Tier 4 engine for this reason. Legendary performance, efficiency and reliability – mtu’s experience in the industrial diesel engine market aims to deliver solutions that address service companies expanding needs and challenges in today's market. Join mtu and CUDD to discuss their Tier 4 fleet expansion and learn more about how a single fleet can cover any pumping scenario.