Geochemistry and isotope chemistry of Michigan Basin brines: Devonian formations
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Controls on lithium content of oilfield waters in Texas and neighboring states (USA)
2024, Journal of Geochemical ExplorationLithium enrichment processes in sedimentary formation waters
2023, Chemical GeologyThe provenance and evolution of thermal spring waters from the Dogai Coring area of Qiangtang basin in Tibet, China
2022, GeothermicsCitation Excerpt :However, the formation and evolution of saline waters in sedimentary basins often involve complex processes. There has never been such a single model that can solve all problems regarding the formation and evolution of saline waters (Wilson et al., 1993). Use of geochemical analysis and isotopic tracer technique allows effectively exploring the provenance and formation process of groundwater containing salt.
Lithium-rich geothermal brines in Europe: An up-date about geochemical characteristics and implications for potential Li resources
2022, GeothermicsCitation Excerpt :Outside Europe, Li-rich deep brines (up to 983 mg/l of Li) are found in some geothermal fields like Salton Sea, in California, USA (Werner, 1970; Elders and Cohen, 1983; Williams and McKibben, 1989; Sanjuan and Millot, 2009), in the Siberian sedimentary platform (Shouakar-Stash et al., 2007; Alekseeva and Alekseev, 2018), or in the Tibet Plateau (Li et al., 2018a; 2019). Average Li contents of oilfield brines are usually below 10 mg/l, but brines with high Li concentrations of up to 500 mg/l occur in some hydrocarbon source rocks (Blake, 1974; Collins, 1975; Connolly et al., 1990; Moldovanyi et al., 1993; Stueber et al., 1993; Wilson and Long, 1993; Chan et al., 2002; Williams and Hervig, 2005; Tabarès, 2013). High Li concentrations have also been observed in deep ocean thermal vents (Garrett, 2004).
Multiple geochemical and isotopic (Boron, Strontium, Carbon) indicators for reconstruction of the origin and evolution of oilfield water from Jiuquan Basin, Northwestern China
2021, Applied GeochemistryCitation Excerpt :Crude oil is commonly associated with the co-production of fluids known as “oilfield water” or “oil-produced water”. Many studies have evaluated the origin of oilfield water (Collins, 1975b; Egeberg and Aagaard, 1989; Fontes and Matray, 1993; Kharaka, 1977; McMahon et al., 2018; McNutt et al., 1987; Surdam and MacGowan, 1987; Williams et al., 2001; Wilson and Long, 1993), their possible migration across basins (Darrah et al., 2015b; Osborn, 2010), and their relationships with different fluids, such as meteoric water (Bein, 1993; Engle et al., 2016; Martini et al., 1998). While oilfield water from conventional oil wells is composed predominantly of formation water, in unconventional tight oil the flowback water is composed of a mixture of the injected hydraulic fracturing fluid and the formation water, with the formation water fraction increasing over time (Balashov et al., 2015; Haluszczak et al., 2013; Kondash et al., 2017; Ni et al., 2018).
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Now at Kent State University, Kent State, Ohio, U.S.A.