Co-Pyrolysis of Woody Biomass and Oil Shale in a Batch Reactor in CO2, CO2-H2O, and Ar Atmospheres

Cerón, Alejandro Lyons; Konist, Alar

doi:10.3390/en16073145

Cited by 3 publications

(2 citation statements)

References 44 publications

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“…For example, this experimental instrument cannot quantitatively describe the fracture propagation process, so we can take a lesson from other research and take more factors into consideration, such as obtaining propagation length, opening width, and growing speed through high-speed imaging devices and image analysis software, and analyzing the influence of pore structure and natural fractures on fracture propagation [41,42], and the corresponding mathematical model needs to be established to describe and calculate it [43][44][45]. This would improve the quantitative analysis of the combined effects of fracturing fluid retention on fracture propagation and formation damage [46].…”

Section: Discussionmentioning

confidence: 99%

Characteristics of Fracturing Fluid Invasion Layer and Its Influence on Gas Production of Shale Gas Reservoirs

Huang

Zhang

Jin³

et al. 2023

Energies

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With the increase of shale gas resource exploitation in our country during recent decades, the situations of low gas production, fast production decline rate, and low flowback rate have been appearing in field production. It is an urgent problem to be solved in shale gas production and it is therefore necessary to study the interaction of the shale gas reservoir and the detained fracturing fluid. In this paper, the Longmaxi Formation shale samples of Sichuan Basin were selected for a water invasion experiment. The fracture propagation law, the water invasion front location, and the water invasion thickness of deep and shallow shale reservoirs after water invasion were compared and analyzed by CT scanning technology. Based on the analysis of the experimental mechanism, a numerical simulation model was established. The dimensionless permeability and thickness of the fracturing fluid invasion layer were introduced to analyze the positive and negative effects of fracturing fluid retention on the reservoir. The results show that during the hydraulic fracturing of shale gas wells, fracturing fluid can quickly enter the complex fracture network, and then slowly enter the shale matrix under various mechanisms to form the fracturing fluid invasion layer. Compared with shallow shale reservoirs, deep shale reservoirs have lower porosity and permeability, which propagates microfractures in the matrix induced by fracturing fluid retention, and results in a smaller fracturing fluid invasion layer thickness. Both the negative effect of fracturing fluid retention on shale damage and the positive effect of microfracture formation and propagation exist simultaneously. The higher the dimensionless fracturing fluid invasion layer permeability, the more complex the fracture network formed in the fractured reservoir will be, resulting in a longer stable production period and a better development effect. When the dimensionless fracturing fluid invasion layer permeability is greater than 1, that is, when the positive effect of fracturing fluid retention is greater, and the thicker the dimensionless fracturing fluid invasion layer is, the better the development effect will be. Combining reservoir characteristics and fracture development, the key to obtaining high productivity of a shale gas well is to optimize the soaking time and the speed of flowback in order to extend the stable production period. In this paper, the characteristics of the fracturing fluid invasion layer and the influence of fracturing fluid retention on gas well productivity are deeply studied, which provides a certain theoretical basis for the optimization of shale gas extraction technology and the improvement of the gas–water two-phase productivity prediction method for fractured horizontal wells.

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Section: Discussionmentioning

confidence: 99%

Characteristics of Fracturing Fluid Invasion Layer and Its Influence on Gas Production of Shale Gas Reservoirs

Huang

Zhang

Jin³

et al. 2023

Energies

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“…Compared with the N 2 injection, the increased pyrolysis weight loss rate of oil shale injected with CO 2 and H 2 O indicated that these compounds were involved in the reaction of organic matter, promoted its cleavage and released the volatile fraction from oil shale [16][17][18]. Figure 1…”

Section: Pyrolysis Behavior Of Oil Shalementioning

confidence: 99%

Study on the pyrolysis behavior and kinetics of Jimusar oil shale with H2O/CO2 injection

Huang,

Kang,

Yang

et al. 2023

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Co-Pyrolysis of Woody Biomass and Oil Shale—A Kinetics and Modelling Study

Lyons Ceron,

Ochieng,

Sarker

et al. 2024

Energies

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The co-pyrolysis of biomass and fossil fuels has been the subject of studies on sustainable energy. Co-feeding oil shale with woody biomass can contribute to a transition into carbon neutrality. The present study analysed the thermal decomposition behaviour of oil shale and biomass blends (0:1, 3:7, 1:1, 7:3, 9:1, and 1:0) through thermogravimetric analysis (TGA) at 80–630 °C with a heating rate of 10 °C/min in CO2 and N2 atmospheres. A comparison of theoretical and experimental residual mass yields of oil shale–biomass mixtures indicated no significant interactions between the fuels. The blends contributed to a decrease of up to 34.4 wt% in solid residues compared to individual pyrolysis of oil shale, and the TGA curves were shifted from up to 10 °C to a lower temperature when the biomass ratio increased. The use of a CO2 atmosphere resulted in the production of solid residues, comparable to the one obtained with the N2 atmosphere. CO2 atmosphere can be used in oil shale–biomass co-pyrolysis, without affecting the decomposition process or increasing the yield of residues. A kinetic model method is proposed based on TGA data at 10, 20, and 30 °C/min. The apparent activation energies for a temperature range of 200–520 °C were in the order of 139, 155, 164, 197, 154, and 167 kJ/mol for oil shale–biomass 0:1, 3:7, 1:1, 7:3, 9:1, and 1:0 blends, respectively. From the isoconversional kinetic analysis, a two-stage pyrolysis was observed, which separated biomass and oil shale pyrolysis. A simulation of biomass and oil shale co-pyrolysis was conducted in Aspen Plus® using TGA-derived kinetic data. The model prediction resulted in a close match with the experimental thermogravimetric data with absolute errors from 1.75 to 3.78%, which highlights the relevance of TGA analysis in simulating co-pyrolysis processes.

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Co-Pyrolysis of Woody Biomass and Oil Shale in a Batch Reactor in CO2, CO2-H2O, and Ar Atmospheres

Cited by 3 publications

References 44 publications

Characteristics of Fracturing Fluid Invasion Layer and Its Influence on Gas Production of Shale Gas Reservoirs

Characteristics of Fracturing Fluid Invasion Layer and Its Influence on Gas Production of Shale Gas Reservoirs

Study on the pyrolysis behavior and kinetics of Jimusar oil shale with H2O/CO2 injection

Co-Pyrolysis of Woody Biomass and Oil Shale—A Kinetics and Modelling Study

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