green energy

fracking-wastewater-has-“shocking”-amount-of-clean-energy-mineral-lithium

Fracking wastewater has “shocking” amount of clean-energy mineral lithium

clean energy, green energy, lithium, Science, syndication / /
fracking operation in Pennsylvania

Enlarge / A hydro-fracking drilling pad for oil and gas operates October 26, 2017 in Robinson Township, Pennsylvania.

A fracking drilling pad operates in the Marcellus Shale formation near Robinson Township, Pa. Credit: Robert Nickelsberg/Getty Images

In 2007, a geoscientist at Penn State named Terry Engelder calculated that Pennsylvania could be sitting on more than 50 trillion cubic feet of accessible natural gas deposits. Engelder later revised his calculation upward, to 489 trillion cubic feet, enough to meet U.S. natural gas demand for 18 years. These massive numbers set off the fracking boom in Pennsylvania, leading to drilling across the state. Since the rush began, there have been 13,000 unconventional wells drilled in Pennsylvania.

Now, a new “astounding” calculation has caught the attention of the gas industry: A study from researchers at the National Energy Technology Laboratory shows the wastewater produced by Pennsylvania’s unconventional wells could contain enough lithium to meet 38 to 40 percent of current domestic consumption. Lithium is a critical mineral that’s an “essential component” of many clean energy technologies, including batteries for electric vehicles. 

The study used chemical and production compliance data from the Pennsylvania Department of Environmental Protection to estimate that approximately 1,160 metric tons of lithium per year could be extracted from this produced water, which is a combination of fluids used for fracking and water from natural formations underground that returns to the surface during the drilling process. The lithium in Pennsylvania’s produced water likely comes from ancient volcanoes that were erupting at the time the natural gas deposits were being formed. This volcanic ash contained lithium that eventually seeped into the water underground.

“The researcher community in the U.S. is really working hard to find the materials and methods that will enable us to meet our climate goals and decarbonize the economy,” said Justin Mackey, the study’s lead investigator. “Sometimes you might be surprised where that material actually comes from.” 

The Marcellus Shale Coalition, an industry trade group dedicated to the Marcellus Shale formation, the natural gas deposit beneath Pennsylvania, West Virginia, Ohio and New York, reacted to the news with enthusiasm. “This scientific analysis by one of the leading energy laboratories in the world shows once again how abundant Pennsylvania natural gas can enhance America’s energy, environmental and national security,” the coalition said in a statement. 

The United States currently relies on imports from Argentina, Chile and China to fully meet its lithium needs, and the demand for lithium is expected to rise dramatically as the clean energy transition accelerates. 

Mackey, a research geochemist at the National Energy Technology Laboratory, said he had focused on lithium because it is a strategic material for the American economy and defense industries and because it has insecure supply chains. “We’re reliant on foreign entities like China and Chile and Australia to source these raw materials, but they’re critical to our economies,” he said. “And more importantly, they’re critical to decarbonizing the U.S. automotive fleet.”

He said the researchers were “shocked” that the highest concentrations of lithium found in the Marcellus “are comparable to lithium brine, to water that is actually being mined for lithium.” 

“I think having more domestic sources of lithium is definitely a positive thing, especially if you don’t have to create a mine to exploit the resource,” Mackey said. Unconventional drilling waste is likely to be produced in large quantities for the foreseeable future, he said, and if remediating this waste safely could also be made economically valuable, that could be beneficial for the environment as well.

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Can we drill for hydrogen? New find suggests additional geological source.

Energy, green energy, hydrogen, Science, Sustainability / /
Image of apartment buildings with mine tailings behind them, and green hills behind those.

Enlarge / Mining operations start right at the edge of Bulqizë, Albania.

“The search for geologic hydrogen today is where the search for oil was back in the 19th century—we’re just starting to understand how this works,” said Frédéric-Victor Donzé, a geologist at Université Grenoble Alpes. Donzé is part of a team of geoscientists studying a site at Bulqizë in Albania where miners at one of the world’s largest chromite mines may have accidentally drilled into a hydrogen reservoir.

The question Donzé and his team want to tackle is whether hydrogen has a parallel geological system with huge subsurface reservoirs that could be extracted the way we extract oil. “Bulqizë is a reference case. For the first time, we have real data. We have a proof,” Donzé said.

Greenish energy source

Water is the only byproduct of burning hydrogen, which makes it a potential go-to green energy source. The problem is that the vast majority of the 96 million tons of hydrogen we make each year comes from processing methane, and that does release greenhouse gases. Lots of them. “There are green ways to produce hydrogen, but the cost of processing methane is lower. This is why we are looking for alternatives,” Donzé said.

And the key to one of those alternatives may be buried in the Bulqizë mine. Chromite, an ore that contains lots of chromium, has been mined at Bulqizë since the 1980s. The mining operation was going smoothly until 2007, when the miners drilled through a fault, a discontinuity in the rocks. “Then they started to have explosions. In the mine, they had a small electric train, and there were sparks flying, and then… boom,” Donzé said. At first, Bulqizë management thought the cause was methane, the usual culprit of mining accidents. But it wasn’t.

Hydrogen at fault

The mine was bought by a Chinese company in 2017, and the new owners immediately sent their engineering teams to deal with explosions. They did measurements and found the hydrogen concentration in the mine’s galleries was around 1–2 percent. It only needs to be at 0.4–0.5 percent for the atmosphere to become explosive. “They also found the hydrogen was coming from the fault drilled through back in 2007. Unfortunately, one of the explosions happened when the engineering team was down there. Three or four people died,” Donzé said.

It turned out that over 200 tons of hydrogen was released from the Bulqizë mine each year. Donzé’s team went there to figure out where all this hydrogen was coming from.

The rocks did not contain enough hydrogen to reach that sort of flow rate. One possible explanation is the hydrogen being released as a product of an ongoing geological process called serpentinization. “But for this to happen, the temperature in the mine would need to reach 200–300 degrees Celsius, and even then, it would not produce 200 tons per year,” said Donzé. “So the most probable was the third option—that we have a reservoir,” he added.

“Probable,” of course, is far from certain.

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Government makes an app to cut down government’s role in solar permitting

Energy, green, green energy, NREL, photovoltaics, renewable energy, Science, solar, Sustainability / /
Aerial view of houses with roof-top solar panels.

Enlarge / NREL has taken some of the hassle out of getting permits for projects like these.

Can government agencies develop software to help cut bureaucratic red tape through automation? The answer is “yes,” according to the promising results achieved by the National Renewable Energy Laboratory (NREL), which has saved thousands of hours of labor for local governments by creating a tool called SolarAPP+ (Solar Automated Permit Processing Plus) for residential solar permits.

“We estimate that automatic SolarAPP+ permitting saved around 9,900 hours of… staff time in 2022,” NREL staff wrote in the report, “SolarAPP+ Performance Review (2022 Data). “Based on median timelines, a typical SolarAPP+ project is permitted and inspected 13 business days sooner than traditional projects… SolarAPP+ has eliminated over 134,000 days in permitting-related delays.”

SolarAPP+ automates over 100 compliance checks in the permitting process that are usually the responsibility of city, county, or town employees, according to Jeff Cook, SolarAPP+ program lead at NREL and first author of the report. It can be more accurate, thorough, and efficient than a time-pressured local government employee would be.

Saving time and money

Sometimes, the cost of permitting can be higher than the cost of solar hardware, Cook said. It depends on the specifics of the project.

“We knew that residential rooftop solar volume was increasing across the country,” Cook said. “It took us… 20 years to get to a million PV installations. And I think we got to 2 million PV installations just a few years later. And so there’s a lot of solar volume out there. And the problem is that each one of those systems needs to be reviewed for code compliance. And so if you need a human to review that, you’ve got a million applications.”

“When regulations make it unnecessarily difficult for people to quickly install solar and storage systems, it hurts everyone,” said Senator Scott Wiener (D-Calif.) in a press statement. “It hurts those who want to install solar. And it hurts communities across California, which are being negatively impacted by climate change. We need to make it easier for people to use renewable energy—that’s just a no-brainer. Expediting solar permitting is something we can do to make this a reality.”

A coalition of stakeholders from the solar industry, the US Department of Energy, and the building code-development community requested that NREL develop the software, Cook said. The organizations represented included UL Solutions and the Interstate Renewable Energy Council. (UL Solutions is a company that addresses a broad range of safety issues; initially, it focused on fire and electrical safety.)

“What we identified is the community need for the software and we identified that there was a gap in the private sector,” Cook said. “There was no incentive to do it from any active members of the private sector, but a real potential opportunity or value to the public good if such a software existed and was publicly available and free for a local government to adopt.”

Cook estimates that hundreds of thousands of hours in plan review time would have been required to manually approve all of the residential solar permits in the United States in recent years. Approving a permit for a residential solar project can take local government staff 15 minutes to an hour, and around 30 percent of the applications are later revised.

A flood of applications

“It just inundates the staff with work that they have to do,” Cook said.

“We are seeing about 750 residential requests over the past 12 months, which is about double the number of applications we saw two years ago,” said Kate Gallego, mayor of Phoenix, at the SolarAPP+ Industry Roundtable. “When I ask people in industry what we can do to speed up deployment of solar, they ask, ‘Can you do permitting faster?’ We’re at about 30 days now. We want to get that permitted as fast as possible, but we don’t want to sacrifice safety, and we want to make sure we’re not just doing it quickly, but well. That’s why this partnership was very attractive to me.”

Up to five separate departments may review the permits—the ones that oversee structural, electrical, fire, planning, and zoning decisions, Cook said.

“There’s usually a queue,” Cook said. “Just because it takes the jurisdiction only 15 minutes to review doesn’t mean that you send it to them today—they review it an hour later and get back to you. The average is, across the country, a seven-day turnaround, but it can be 30 days plus. It really varies across the country depending on how much volume of solar is in that space.”

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