Mineral Reactions in Shale Gas Reservoirs: Barite Scale Formation from Reusing Produced Water As Hydraulic Fracturing Fluid

Vankeuren, Amelia N. Paukert; Hakala, J. Alexandra; Jarvis, Karl; Moore, Johnathan

doi:10.1021/acs.est.7b01979

Cited by 120 publications

(136 citation statements)

References 70 publications

(119 reference statements)

Supporting

Mentioning

126

Contrasting

Order By: Relevance

“…HCl is a common additive used to prevent scaling of secondary minerals and was also used in creating the synthetic HFF used in this study. The pH rose to nearly 6 in samples LM-2 and MIP-3H (Table 3) indicating that carbonate minerals in these shale samples acted as effective buffers during the reaction similar to prior observations (Vankeuren et al, 2017). (Table 3), LM-2 21% and MIP-3H 16%, acted as effective buffers and increased pH of effluent closer to neutral, thereby limiting the amount of pyrite dissolution that could occur.…”

Section: Discussion 241 Aqueous Inorganic Chemistrysupporting

confidence: 79%

“…During this shut-in phase, HFF reacts with the shale rock in reservoir at a relatively high temperature and pressure conditions. In situ conditions and residence time in the subsurface alter the fluid significantly and provide a distinct chemical signature to the flowback and produced fluid that is very different from the initial injection fluid (Vankeuren et al, 2017).…”

Section: Hydraulic Fracturing Fluid (Hff)mentioning

confidence: 99%

“…Significant variations in mineralogy and maturity throughout the basin and the utilization of unique mixtures of HFF make it difficult to comprehensively assess chemical signatures of produced fluid from different parts of the reservoir. Many studies provide evidence of mineral dissolution, and precipitation (He and Vidic, 2016, Marcon et al, 2016, Vankeuren et al, 2017 and elevated levels of dissolved organic carbon (DOC) observed in fluids returning to the surface (Abualfaraj et al, 2014).…”

Section: Compounds Observed In Produced Fluid From Marcellus Shalementioning

confidence: 99%

“…The (Vankeuren et al, 2017). Once returned to the surface, the fluid is considered produced water, and to efficiently recycle or dispose of this fluid, it is critical that we understand the reactions taking place between the organic-rich shale reservoir and HFF under in situ reservoir conditions.…”

Section: Introductionmentioning

confidence: 99%

“…varying concentrations of dissolved organic carbon (DOC), and sometimes an abundance of radioactive elements (Vankeuren et al, 2017). All of these chemical components create complexities when trying to reuse and recycle produced fluid.…”

Section: Introductionmentioning

confidence: 99%

See 4 more Smart Citations

Effect of maturity and mineralogy on fluid-rock reactions in the Marcellus Shale

Pilewski

Sharma

Hakala

et al. 2019

Environ. Sci.: Processes Impacts

Self Cite

View full text Add to dashboard Cite

EFFECT OF MATURITY AND MINERALOGY ON FLUID-ROCK REACTIONS IN THE MARCELLUS SHALE John PilewskiThe advancement in drilling technology and discoveries of large quantities of natural gas in the United States has led to a substantial increase in hydraulic fracturing (HF) operations in the past two decades. The Marcellus Shale is a world-renowned source rock that has been extensively exploited via HF, and this study aims to analyze the complex chemical reactions that take place during this process of hydrocarbon extraction. Fluid-shale reactions were conducted using a mixture of synthetic brine, and synthetic hydraulic fracturing fluid reacted with three shale samples of varying maturity and mineralogy. Static autoclave reactors were used to mimic in situ reservoir reaction parameters, roughly 2,500 psi and 100°C respectively. Reactions were carried out for 14 days in accordance with the shut-in time when fluid remains in the reservoir during the HF process. The chemical analysis focused on observing major changes in ionic species concentrations and the proliferation of low molecular weight organic compounds with respect to maturity and mineralogy. Shale samples LM-2 and MIP-3H containing relatively greater amounts of carbonate minerals reacted as buffering agents during the reaction increasing the effluent pH to near neutral. Ion Chromatography results indicate an increase in sulfate and phosphate ions and decrease in barium ions in all fluid-shale effluents. These results suggest that the relative abundance of minerals, particularly calcite and pyrite, affect mineral dissolution and precipitation during HF operations. Results also show organic acids are generated in the control fluid, HPT-PF, by placing it under high pressure/temperature conditions without any shale interaction. Overall dissolved organic carbon concentrations decrease in all effluent samples compared to the control fluid. The GC-MS analysis focused on the observation of benzene, toluene, ethylene, and xylene (BTEX) analytes. Results indicate toluene and xylene were generated in the control fluid, HPT-PF, without any shale interaction. The least mature LM-2 sample generated effluent containing the highest concentrations of target VOC analytes, and the most mature MIP-3H sample generated no observable analytes. These results suggest that HFF additives are being transformed at reservoir pressure/temperature conditions, low mature shale is releasing geogenic, labile organic compounds, and high mature shale is adsorbing any VOCs generated from HF processes.iii

show abstract

Section: Discussion 241 Aqueous Inorganic Chemistrysupporting

confidence: 79%

Section: Hydraulic Fracturing Fluid (Hff)mentioning

confidence: 99%

Section: Compounds Observed In Produced Fluid From Marcellus Shalementioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

See 3 more Smart Citations

Effect of maturity and mineralogy on fluid-rock reactions in the Marcellus Shale

Pilewski

Sharma

Hakala

et al. 2019

Environ. Sci.: Processes Impacts

Self Cite

View full text Add to dashboard Cite

show abstract

Geochemical phenomena between Utica‐Point Pleasant shale and hydraulic fracturing fluid

2019

View full text Add to dashboard Cite

This study evaluated geochemistry between the Utica-Point Pleasant shale and reservoir/hydraulic fracturing fluid mixtures under simulated reservoir conditions in a batch reactor system. Analytical techniques were utilized to monitor fluid composition with time along with pre-and post-trial shale microscopy and phase identification analyses. Formation of iron-based precipitate was evident through results from fluid and material analyses. Ferrous iron was the predominant iron form found in the aqueous phase, with oxidation to ferric iron and subsequent precipitate formation. Geochemical modeling further supported ferric iron was the favorable phase for precipitation. K E Y W O R D S crystallization (precipitation), geochemical, hydraulic fracturing, oil shale/tar sands, reaction kinetics 1 | INTRODUCTION U.S. tight oil has had a tremendous impact on stabilizing global oil prices and increasing energy security. Such light crude is recovered from low permeability rock formations, primarily shale, using unconventional methods such as horizontal drilling with hydraulic fracturing. As of March 2019, the Energy Information Association (EIA) reports approximately 60% total U.S. oil production comes from tight oil. 1 While unconventional wells have shown promise in terms of oil production, economic viability is still uncertain due to rapid production decline leading to shorter well life. Peak performance of an unconventional oil well occurs during the first quarter of production, with up to 74% production decline after 1 year. 2 Solutions explored to counteract production decline include refracturing or other enhanced oil recovery methods. Simulation studies have been developed to evaluate the effects of stimulation techniques on production to determine if profitable recovery is feasible. 3-5 Although simulation of refracturing and enhanced oil recovery methods have shown promise, these techniques do not fully account for phenomena encountered in unconventional wells. Various approaches have been utilized to mimic downhole phenomena. 6-8 An approach by Luo evaluated confinement effects on hydrocarbon bubble point. This study found octane and decane confined in nanoporous media possess two distinct bubble point temperatures, with lower/higher bubble point temperatures differing ±15 K in comparison to respective bulk properties. 6 By understanding various in-situ well phenomena, proper recovery analysis can be performed and modifications to hydraulic fracturing processes can be developed to increase well productivity and lifetime. 9 Aqueous phase chemical reactions are another key phenomenon occurring in shale reservoirs. Such reactions occur during well completion, when hydraulic fracturing fluid (HFF) mixes with rock and formation water, potentially causing precipitate formation, more commonly referred to as scale. Scales form when dissolved solid concentrations This contribution was identified by Rameshwar Srivastava (Department of Energy) as the Best Presentation in the session "New Technologies to Enhance the Productio...

show abstract

Hydrochemistry, Sources and Management of Fracturing Flowback Fluid in Tight Sandstone Gasfield in Sulige Gasfield (China)

Shi¹,

He²,

Zhou³

et al. 2023

Arch Environ Contam Toxicol

View full text Add to dashboard Cite

Mineral Reactions in Shale Gas Reservoirs: Barite Scale Formation from Reusing Produced Water As Hydraulic Fracturing Fluid

Cited by 120 publications

References 70 publications

Effect of maturity and mineralogy on fluid-rock reactions in the Marcellus Shale

Effect of maturity and mineralogy on fluid-rock reactions in the Marcellus Shale

Geochemical phenomena between Utica‐Point Pleasant shale and hydraulic fracturing fluid

Hydrochemistry, Sources and Management of Fracturing Flowback Fluid in Tight Sandstone Gasfield in Sulige Gasfield (China)

Contact Info

Product

Resources

About