scholarly journals Effect of Fault Architecture and Permeability Evolution on Response to Fluid Injection

2018 ◽  
Vol 123 (11) ◽  
pp. 9982-9997 ◽  
Author(s):  
Alissar Yehya ◽  
Zhuo Yang ◽  
James R. Rice
Keyword(s):  
Fluid Injection ◽  
Permeability Evolution ◽  
Fault Architecture

POROSITY AND PERMEABILITY EVOLUTION ACCOMPANYING HOT FLUID INJECTION INTO DIATOMITE

2001 ◽  
Vol 19 (9-10) ◽  
pp. 1167-1185 ◽  
Author(s):  
I. Diabira ◽  
L. M. Castanier ◽  
A. R. Kovscek
Keyword(s):  
Fluid Injection ◽  
Permeability Evolution ◽  
Porosity And Permeability

Dynamic permeability evolution during fluid injection and production in ultra-deep geothermal reservoirs

2021 ◽  
Author(s):  
Samuel Scott ◽  
Alina Yapparova ◽  
Philipp Weis ◽  
Matthew Houde
Keyword(s):  
High Pressure ◽  
Porphyry Copper ◽  
Pure Water ◽  
Hydrothermal Systems ◽  
Heat Fluxes ◽  
Fluid Injection ◽  
Permeability Evolution ◽  
Permeability Model ◽  
Geothermal Resources ◽  
Dynamic Permeability

<p>A geothermal well drilled into a reservoir at temperatures exceeding the critical point of pure water (>374 °C) could generate substantially greater quantities of energy than conventional geothermal wells. Although these temperatures can be found at shallow depths (<2-3 km) in high-grade geothermal resources located in volcanically active areas, similar temperatures are only found at depths >10 km beneath vast areas of continental crust with lower heat fluxes. Permeability decreases markedly with increasing depth below 2-3 km, so exploiting the tremendous heat resources of high temperature rock at such great depths will require permeability stimulation by the injection of high-pressure fluids. In this study, we use the CSMP++ platform to perform 3D simulations of transient permeability evolution around a geothermal doublet drilled to depths between 10-16 km. The simulations incorporate a well model initially devised by Peaceman (1978) to calculate well pressures and rates of fluid production/injection. The dynamic permeability model is based on Weis et al. (2012), initially developed to simulate the evolution of ore-forming magmatic-hydrothermal systems, and links a failure criterion for critically-stressed crust with depth-dependent permeability profiles characteristic for tectonically active crust as well as pressure- and temperature-dependent relationships describing hydraulic fracturing and the transition from brittle to ductile rock behavior. We investigate the permeability changes in response to high-pressure fluid injection in brittle and ductile rock, the timescales over which the zone of permeability stimulation migrates towards production wells, and dynamic permeability evolution in response to changes in injection and production parameters. These simulations aim to mitigate resource risks that could limit the ability to extract heat from geothermal resources in ductile upper crust and to help anticipate the conditions that would be required to make the exploitation of ultra-deep supercritical geothermal resources a reality. </p><p>References</p><p>Peaceman, D. W. (1978) Interpretation of Well-Block Pressures in Numerical Reservoir Simulation. SPE 6893, 183–194.</p><p>Weis, P., Driesner, T., & Heinrich, C. A. (2012). Porphyry-copper ore shells form at stable pressure-temperature fronts within dynamic fluid plumes. Science, 338(6114), 1613–1616.</p>

A new approach to the hydraulic fracture geometric dimensions determination

2017 ◽  
Vol 12 (1) ◽  
pp. 126-134
Author(s):  
A.M. Ilyasov
Keyword(s):  
Exact Solution ◽  
Hydraulic Fracture ◽  
Pressure Gauge ◽  
Hyperbolic Type ◽  
Fluid Injection ◽  
Fracturing Fluid ◽  
New Approach ◽  
Gauge Data ◽  
Bottomhole Pressure ◽  
Half Length

Based on the generalized Perkins-Kern-Nordgren model (PKN) for the development of a hyperbolic type vertical hydraulic fracture, an exact solution is obtained for the hydraulic fracture self-oscillations after terminating the fracturing fluid injection. These oscillations are excited by a rarefaction wave that occurs after the injection is stopped. The obtained solution was used to estimate the height, width and half-length of the hydraulic fracture at the time of stopping the hydraulic fracturing fluid injection based on the bottomhole pressure gauge data.

INDUCED SEISMICITY ASSOCIATED WITH WASTE FLUID INJECTION WELLS

2017 ◽  
Author(s):  
Megan MacDonald ◽  
◽  
John E. Ebel
Keyword(s):  
Induced Seismicity ◽  
Fluid Injection ◽  
Injection Wells

Simulation of proppant transport and fracture plugging in the framework of a radial hydraulic fracturing model

2020 ◽  
Vol 35 (6) ◽  
pp. 325-339
Author(s):  
Vasily N. Lapin ◽  
Denis V. Esipov
Keyword(s):  
Numerical Model ◽  
Hydraulic Fracturing ◽  
Oil And Gas ◽  
Oil And Gas Industry ◽  
Injection Rate ◽  
Fluid Injection ◽  
Subtraction Technique ◽  
Gas Industry ◽  
Proppant Transport ◽  
Hydraulic Fracture Propagation

AbstractHydraulic fracturing technology is widely used in the oil and gas industry. A part of the technology consists in injecting a mixture of proppant and fluid into the fracture. Proppant significantly increases the viscosity of the injected mixture and can cause plugging of the fracture. In this paper we propose a numerical model of hydraulic fracture propagation within the framework of the radial geometry taking into account the proppant transport and possible plugging. The finite difference method and the singularity subtraction technique near the fracture tip are used in the numerical model. Based on the simulation results it was found that depending on the parameters of the rock, fluid, and fluid injection rate, the plugging can be caused by two reasons. A parameter was introduced to separate these two cases. If this parameter is large enough, then the plugging occurs due to reaching the maximum possible concentration of proppant far from the fracture tip. If its value is small, then the plugging is caused by the proppant reaching a narrow part of the fracture near its tip. The numerical experiments give an estimate of the radius of the filled with proppant part of the fracture for various injection rates and leakages into the rock.

Numerical simulation of fluid injection-induced fault slip in heterogeneous shale formations

2021 ◽  
Vol 134 ◽  
pp. 104120
Author(s):  
Yijin Zeng ◽  
Qinghua Lei ◽  
Zineng Wang ◽  
Shidong Ding ◽  
Kui Liu ◽  
...  
Keyword(s):  
Numerical Simulation ◽  
Fault Slip ◽  
Fluid Injection ◽  
Shale Formations
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