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Interpretation of Hydraulic Fractures Based on Microseismic Response in the Marcellus Shale, Monongalia County, West Virginia, USA: Implications for Shale Gas Production
Summary Hydraulic fracturing is critical for extracting shale gas in the subsurface. The treatment technique of multistage hydraulic fracturing is widely used to maximize production. In multistage hydraulic fracturing, not all pumping stages make the same contribution for production, although the designed stimulation process is almost same in every pumping stage. In this study, we characterize the microseismic responses of hydraulic fracturing. Significant variations of microseismic characteristics are observed among the different pumping stages. Pre-existing natural fractures are examined along the horizontal well in selected stages. Combined with the Mohr’s circle analysis, results of the fracture study show that induced hydraulic fractures can be captured by pre-existing natural fractures. Induced hydraulic fractures are simulated by the unconventional fracture model (UFM), and the result reveals that the stress-shadow effect diverts the direction of hydraulic fractures. The diverted hydraulic fracture affects the development of the hydraulic fracture network, which has influence on production. The treatment of two-step pumping is investigated by application of hydraulic diffusivity. Hydraulic fracturing performance and production could be optimized by the treatment of two-step pumping in a single stage. The second pumping creates new fractures and fills the fractures with additional proppants to maintain production for a long duration.
Sustainable Management of Flowback Water during Hydraulic Fracturing of Marcellus Shale for Natural Gas Production
This study evaluated the feasibility of using abandoned mine drainage (AMD) as make- up water for the reuse of produced water for hydraulic fracturing. There is an abundance of AMD sources near permitted gas wells as documented in this study that can not only serve as makeup water and reduce the demand on high quality water resources but can also as a source of chemicals to treat produced water prior to reuse. The assessment of AMD availability for this purpose based on proximity and relevant regulations was accompanied by bench- and pilot-scale studies to determine optimal treatment to achieve desired water quality for use in hydraulic fracturing. Sulfate ions that are often present in AMD at elevated levels will react with Ba²⁺ and Sr²⁺ in produced water to form insoluble sulfate compounds. Both membrane microfiltration and gravity separation were evaluated for the removal of solids formed as a result of mixing these two impaired waters. Laboratory studies revealed that neither AMD nor barite formed in solution had significant impact on membrane filtration but that some produced waters contained submicron particles that can cause severe fouling of microfiltration membrane. Coagulation/flocculation was found to be an effective process for the removal of suspended solids and both bench- and pilot-scale studies revealed that optimal process conditions can consistently achieve the turbidity of the finished water below 5 NTU. Adjusting the blending ratio of AMD and produced water can achieve the desired effluent sulfate concentration that can be accurately predicted by chemical thermodynamics. Co-treatment of produced water and AMD will result in elevated levels of naturally occurring radioactive materials (NORM) in the solid waste generated in this process due to radium co-precipitation with barium sulfate. Laboratory studies revealed that the mobility of barite that may form in the subsurface due to the presence of sulfate in the fracturing fluid can be controlled by the addition of appropriate antiscalants.
Data Report for Monitoring at Six West Virginia Marcellus Shale Development Sites using NETL’s Mobile Air Monitoring Laboratory (July–November 2012)
The West Virginia Department of Environmental Protection’s Office of Oil and Gas was directed according to the Natural Gas Horizontal Well Control Act of December 14, 2011 (West Virginia Code §22-6A) to conduct studies of horizontal well drilling activities related to air quality. The planned study, “Noise, Light, Dust, Volatile Organic Compounds Related to Well Location Restrictions,” required determination of the effectiveness of a 625 ft minimum set-back from the center of the pad of a horizontal well drilling site to the nearest occupied dwelling. An investigation was conducted at seven drilling sites by West Virginia University (WVU) and the National Energy Technology Laboratory (NETL) to collect data on dust, hydrocarbon compounds and on noise, radiation, and light levels. NETL’s role in this study was to collect measurements of ambient pollutant concentrations at six of the seven selected sites using NETL’s Mobile Air Monitoring Laboratory. The trailer-based laboratory was situated a distance of 492–1,312 ft from each well pad, on which activities included well pad construction, vertical drilling, horizontal drilling, hydraulic fracturing, and flaring, with the objective of evaluating the air quality impact of each activity for 1–4 weeks per site. Measured pollutants included volatile organic compounds (VOCs), coarse and fine particulate matter (PM 10 and PM 2.5 , respectively), ozone, methane (CH 4 ), carbon dioxide (CO 2 ), carbon isotopes of CH 4 and CO 2 , organic carbon (OC), elemental carbon (EC), oxides of nitrogen (NOx), and sulfur dioxide (SO 2 ).
Simulation and Analysis of North American natural gas Supply and Delivery during a Winter High-Demand Event with Loss of Marcellus Production
This report presents analyses of the predicted response of the North American natural gas system to extremely high natural gas demand during the winter seasons of 2015 and 2030. These high-demand scenarios were simulated both with and without freeze- off of a fraction of Appalachia shale gas wells in January 2015 and 2030 that cause a loss of approximately 3% of total national production. Profiles of gas consumption, supply, price, and storage results are compared with those expected during normal conditions. The impacts of increased demand, with and without Appalachia production loss, are described for the United States and for its nine census regions.
Unconventional critical mineral resources in Marcellus and Bakken Shale Formations
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What is Produced Water Worth? The Total Value Proposition in the Marcellus Formation and Permian Basin
Produced water is a byproduct of oil and gas extraction and is known to contain lithium, a critical mineral. Produced water can also contain other minerals and commodities that are recoverable and have economic value. Here we focus on estimating the total value proposition of produced water in two important basins. That is, we assess the potential ‘sale price’ of all commodities that could be reasonably extracted from a unit volume of produced water. This value estimate helps better understand the economic and technological opportunities associated with produced water.
Gel diffusion studies on factors affecting barite scaling in Marcellus shale gas wells
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Unconventional: The Development of Natural Gas from the Marcellus Shale
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Laboratory Scale Hydraulic Fracture of Marcellus Shale.
Abstract not provided.
Laboratory Scale Hydraulic Fracture of Marcellus Shale.
Abstract not provided.
Laboratory Scale Hydraulic Fracture of Marcellus Shale.
Abstract not provided.
Fracture Permeability and Evolution of Marcellus Shale
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