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Water management in oil and gas operations has become an industry itself. According to Bluefield’s report, “Midstream Water Management: U.S. Hydraulic Fracturing Strategies, Solutions & Outlook,” water management for hydraulic fracturing has been steadily growing from 2017. All indicators, according to the same report, say this trend will be kept for the next few years.

As demands for water management solutions increase, service companies are looking for new ways to optimize their ability to recycle and store this water. 

Total Water Management Spent 2011 - 2028

Total Water Management Spent 2011 - 2028

According to Evan Tikka, senior consultant, at Wood Mackenzie, the water midstream sector growth can now be associated with long-term acreage dedications. WaterBridge has acquired almost 10 different systems which resulted in a 10-plus-year acreage dedication. ”From an E&P perspective, it’s been a year of a trust as we’ve started to see some of the larger U.S. independent and supermajors’ views change on the types of contracts and types of relationships that they’re willing to enter into with the water midstream players, characterized by longer-term acreage dedications and some larger divestments.”, Tikka says.

When asked if more E&P companies will be selling their water infrastructure assets to water midstream companies, Matthias Bloennigen, director of upstream consulting at Wood Mackenzie said ”The short answer is yes.” He also said that water midstream companies need to be thorough when researching assets to be purchased because E&P companies are selling ”their less strategic and underutilized water infrastructure assets”. Although these purchases may be risky for water midstream companies, there is a clear opportunity for them if they manage to integrate infrastructure and increase utilization.

From what cost is concerned, Laura Capper, president and CEO of EnergyMakers Advisory Group, stated ”Cost is absolutely a key driver to overall oil and gas profitability.” She also pointed out that for the big players, cost with water management will decrease over time as volume and resource contributes to the effectiveness of the water management programs. Smaller players will however have a more difficult time in keeping the costs low in the long run.

When referring to the challenges that water teams are facing in the year ahead, Rob Bruant, director of products at B3 Insights said ”Things will continue to be challenging on the regulatory front.”  As an example, due to current regulations, New Mexico operators will have greater costs to dispose of the water into deeper formations. ”There is going to be a continued net movement of water from New Mexico to Texas, where the regulations are getting stricter but not nearly as strict.”

Andy Adams, director of water management and infrastructure for Select Energy Services, said ”The greatest issue I see is the logistical challenges of managing and sharing water. Everybody wants to share the water; everybody wants to reuse produced water. But the most difficult aspect of this is actually managing the logistics of delivering the water safely and on time.”

You can get more information on water management in oil and gas operations by signing up for a Free Energy Datalink account.

Source:  https://www.hartenergy.com/exclusives/bringing-balance-water-demands-186176

What you need to Know About the Sale of BHP's Oil Business

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BHP announced the sale of its oil business to Woodside Petroleum to happen in the middle of 2022. Both companies stocks dropped reflecting investor’s concerns. Woodside Petroleum is yet to show the improved post-COVID performance. The deal when closed would make Woodside Petroleum a new “super independent”.

There Are Issues to Deal With Before Rover Can Start Up

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Energy Transfer has a list of tasks from FERC to complete

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Oil output in the Permian Basin in Texas and New Mexico is supposed to go up 88,000 bbl/d to a record 5.219 million bbl/d in June, as the U.S. Energy Information Administration (EIA) announced in its report on May 16. Additionally, gas productivity in the Permian Basin and the Haynesville in Texas, Louisiana and Arkansas will rise to record highs of 20 Bcf/d and 15.1 Bcf/d in June, respectively. Given that this growth has been expected, recent global market changes make forecasting the output even more challenging. Learning how production will change is easier with early activity tracking, a new service recently launched by Rextag – Pad Activity Monitor. With the help of PAM, you are able to monitor well pad clearing, drilling operations, fracking crew deployment and completions with new data collected approximately every 2 days. Additionally, it cuts down activity reporting lag times by at least 98%, from 120-180 days down to just 5-8 days. In order to access reports, charts, tables, and mapping visualizations via Rextag’s Energy DataLink use a web-based application allowing users to filter, download and identify activity on a map or data table. Moreover, customers will be able to set up daily, weekly, and monthly email report notifications.

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The EIA forecasts that total output in the main U.S. shale oil basins will increase 142,000 bbl/d to 8.761 million bbl/d in June, the most since March 2020. Oil productivity in the Permian Basin in Texas and New Mexico is supposed to go up 88,000 bbl/d to a record 5.219 million bbl/d in June, as the U.S. Energy Information Administration (EIA) announced in its report on May 16. In the largest shale gas basin, the productivity in Appalachia in Pennsylvania, Ohio and West Virginia will grow up to 35.7 Bcf/d in June, its highest since beating a record 36 Bcf/d in December 2021. Gas output in the Permian Basin and the Haynesville in Texas, Louisiana and Arkansas will rise to record highs of 20 Bcf/d and 15.1 Bcf/d in June, respectively. Speaking of the Permian future output, putting hands on upcoming changes in production has recently been made easier with the new Rextag's service - Pad Activity Monitor. Thanks to satellite imagery and artificial intelligence, customers are able to monitor the oil and gas wells and are provided with near real-time activity reports related to drilling operations. However, it is noticed that productivity in the largest oil and gas basins has decreased every month since setting records of new oil well production per rig of 1,544 bbl/d in December 2020 in the Permian Basin, and new gas well production per rig of 33.3 MMcf/d in March 2021 in Appalachia.

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No sooner had the crude prices soared above $100/bbl than the industry professionals believed in an incredible growth of drilling activity in North America’s largest shale patch. Analysts speculate that additional output of 500,000 barrels of oil daily would become a significant part (4%) of overall U.S. daily production. That is going to flatter oil and gasoline prices. Drilling permits in the Permian Basin are persistently growing, averaging approximately 210 at the beginning of April. Moreover, the permits trend is noticed as an all-time high as a total of 904 horizontal drilling permits were awarded last month. Nowadays, learning and analysing the current situation and predicting the future development become easier with early activity tracking, a new service recently launched by Rextag. Rextag's Pad Activity monitor (PAM) allows you to see well pad clearing, drilling operations, fracking crew deployment and completions with new data collected approximately every 2 days with the help of satellite imagery and artificial intelligence. While the increase in drilling will result in higher production, U.S. shale producers will have to overcome several hurdles including labor shortages and supply constraints.

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