The strontium isotopic evolution of Marcellus Formation produced waters, southwestern Pennsylvania

Capo, Rosemary C.; Stewart, Brian W.; Rowan, Elisabeth L.; Kohl, Courtney A. Kolesar; Wall, A. J.; Chapman, Elizabeth C.; Hammack, Richard; Schroeder, Karl

doi:10.1016/j.coal.2013.12.010

Cited by 76 publications

(52 citation statements)

References 48 publications

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“…Capo et al (2014) suggested that chemical constituents in the produced water could originate from HF fluid-induced salt dissolution in the fractured zone, along with mobilization of brine inclusions and brine from adjacent formations. However, it is not clear to what extent the dissolved solids in flowback water originate from connate Marcellus Formation waters or dissolution of salt by the fracturing fluids.…”

Section: Origin Of Tds In Flowbackmentioning

confidence: 98%

Evolution of water chemistry during Marcellus Shale gas development: A case study in West Virginia

Ziemkiewicz

2015

Chemosphere

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Section: Origin Of Tds In Flowbackmentioning

confidence: 98%

Evolution of water chemistry during Marcellus Shale gas development: A case study in West Virginia

Ziemkiewicz

2015

Chemosphere

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“…7-9. Marcellus Shale recycled fracturing fluid commonly contains strontium, barium, and sulfate, which explains the precipitation of minerals bearing these elements on the Huntersville Chert surface [1,12,7,5,10,3,25]. Mineral precipitation occurred in high quantities and limited the relocation of six out of ten initial features to be identified via FE-SEM.…”

Section: Effects Of Fracturing Fluid On the Huntersville Chertmentioning

confidence: 99%

“…Flowback water from Marcellus Shale wells represents an environmental concern due to high salinity, total dissolved solids (TDS), and leachates from naturally occurring radioactive material (NORM) [12,7,1,5,10,3,24]. As a result of the complex chemistry and environmentally hazardous nature of flowback water, costly treatment was previously conducted via transportation to waste water facilities capable of handling high TDS fluids.…”

Section: Introductionmentioning

confidence: 99%

Characterization of Marcellus Shale and Huntersville Chert before and after exposure to hydraulic fracturing fluid via feature relocation using field-emission scanning electron microscopy

Dieterich

Kutchko

Goodman

2016

Fuel

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a b s t r a c tTwo sets of experimental in situ fluid-rock interaction studies were implemented to understand the interactions between hydraulic fracturing fluid and rocks of the Marcellus Shale gas play. Marcellus Shale and Huntersville Chert core samples were exposed to synthetically prepared fracturing fluid and recycled fracturing fluid from the field, respectively, and examined before and after in situ exposure using surface relocation techniques via high-resolution field-emission scanning electron microscopy (FE-SEM) to investigate chemical or physical alterations.Results indicate that in situ pressure promoted fracture growth along the sedimentological (horizontal) bedding plane of the Marcellus Shale samples. Moreover, calcium carbonate (CaCO 3 ) dissolution was observed and gypsum (CaSO 4 ⁄ 2H 2 O) appeared to precipitate both on the surface and in the numerous fractures. Barite (BaSO 4 ), strontianite (SrCO 3 ), celestine (SrSO 4 ), and apatite (CaPO 4 ) formed a unique pattern of precipitates on the surface of the Huntersville Chert samples. Additionally, Rhenium and rare earth element (REE) Europium were identified in minerals which precipitated on the Huntersville Chert surface identified by FE-SEM spectral analysis.Published by Elsevier Ltd.

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“…KCl = potassium chloride. signature in Marcellus Shale produced water relative to the overlying formations in the Appalachian Basin confirms the application of strontium isotopic ratios as valuable tracers of potential migration of Marcellus water into shallow aquifers (Chapman et al, 2012;Capo et al, 2014). Potential source brines, i.e., Silurian brines, are commonly found in rock units underneath the Marcellus Shale in Pennsylvania (Warner et al, 2012;Haluszczak et al, 2013).…”

Section: Intersection With Natural Fractures?mentioning

confidence: 82%

“…Water cut could be derived from existing natural fractures within the black shale interval, additionally intersected and mobilized by hydraulic fractures (hypothesis 1: QHS pore water). Even a pore-related storage of formation water seems to be feasible, as suggested for brines from porous lenses of organic matter within the Marcellus Shale (Capo et al, 2014).…”

Section: Intersection With Natural Fractures?mentioning

confidence: 97%

Recovery rates of fracturing fluids and provenance of produced water from hydraulic fracturing of Silurian Qusaiba hot shale, northern Saudi Arabia, with implications on fracture network

Birkle

2016

Bulletin

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Geochemical fingerprinting of produced water from hydraulic fracturing projects is an essential tool to trace their provenance during the postfracturing period, to quantify recovery rates and volumes of fracturing fluids, and to visualize the geodynamic structure of natural or induced fracture networks. A total of 41 produced water samples from an exploration well in the Northern Arabia Exploration Area in Saudi Arabia were collected daily from the fracture-stimulated Qusaiba hot shale and analyzed for major ions and trace elements and partially for environmental isotopes. The postfracturing period shows an initial return of supply water and potassium chloride brine, subsequently replaced by the inflow of sodium chloride-type formation water with a stable plateau salinity of 50,000 mg/L. Less than 10% of the total injected fracturing fluids were recovered during postfracturing, whereas 78.8 vol. % of the total recovered fluid is composed of formation water (20,843 out of 26,446 bbls) during the study period. Coinciding values between logged reservoir temperature and calculated geothermometers confirm the provenance of pore water from the Qusaiba hot shale or from nearby units. The recharge of the Silurian sequence with meteoric surface water occurred during the early Holocene (6-6.7 ka), as evidenced by geochronological dating with the 14 C method and d 18 O/d 2 H values close to the global meteoric water line. The inflow of formation A U T H O R SPeter Birkle~Geology Technology Team,

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The strontium isotopic evolution of Marcellus Formation produced waters, southwestern Pennsylvania

Cited by 76 publications

References 48 publications

Evolution of water chemistry during Marcellus Shale gas development: A case study in West Virginia

Evolution of water chemistry during Marcellus Shale gas development: A case study in West Virginia

Characterization of Marcellus Shale and Huntersville Chert before and after exposure to hydraulic fracturing fluid via feature relocation using field-emission scanning electron microscopy

Recovery rates of fracturing fluids and provenance of produced water from hydraulic fracturing of Silurian Qusaiba hot shale, northern Saudi Arabia, with implications on fracture network

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