A Mechanistic Model for Formation Damage and Fracture Propagation During Water Injection

2005 ◽  
Author(s):  
Ahmed S. Abou-Sayed ◽  
Karim S. Zaki
Keyword(s):  
Mechanistic Model ◽  
Water Injection ◽  
Fracture Propagation ◽  
Formation Damage ◽  
Damage And Fracture

scholarly journals Investigation of Water Composition on Formation Damage and Related Energy Recovery from Geothermal Reservoirs: Geochemical and Geomechanics Insights

Energies ◽  
2021 ◽  
Vol 14 (21) ◽  
pp. 7415
Author(s):  
Ilyas Khurshid ◽  
Imran Afgan
Keyword(s):  
Geothermal Energy ◽  
Water Injection ◽  
Formation Damage ◽  
Breakdown Pressure ◽  
Geothermal Reservoirs ◽  
Water Composition ◽  
Porosity Reduction ◽  
Reduction Case ◽  
Formation Porosity

The main challenge in extracting geothermal energy is to overcome issues relating to geothermal reservoirs such as the formation damage and formation fracturing. The objective of this study is to develop an integrated framework that considers the geochemical and geomechanics aspects of a reservoir and characterizes various formation damages such as impairment of formation porosity and permeability, hydraulic fracturing, lowering of formation breakdown pressure, and the associated heat recovery. In this research study, various shallow, deep and high temperature geothermal reservoirs with different formation water compositions were simulated to predict the severity/challenges during water injection in hot geothermal reservoirs. The developed model solves various geochemical reactions and processes that take place during water injection in geothermal reservoirs. The results obtained were then used to investigate the geomechanics aspect of cold-water injection. Our findings presented that the formation temperature, injected water temperature, the concentration of sulfate in the injected water, and its dilution have a noticeable impact on rock dissolution and precipitation. In addition, anhydrite precipitation has a controlling effect on permeability impairment in the investigated case study. It was observed that the dilution of water could decrease formation of scale while the injection of sulfate rich water could intensify scale precipitation. Thus, the reservoir permeability could decrease to a critical level, where the production of hot water reduces and the generation of geothermal energy no longer remains economical. It evident that injection of incompatible water would decrease the formation porosity. Thus, the geomechanics investigation was performed to determine the effect of porosity decrease. It was found that for the 50% porosity reduction case, the initial formation breakdown pressure reduced from 2588 psi to 2586 psi, and for the 75% porosity reduction case it decreased to 2584 psi. Thus, geochemical based formation damage is significant but geomechanics based formation fracturing is insignificant in the selected case study. We propose that water composition should be designed to minimize damage and that high water injection pressures in shallow reservoirs should be avoided.

Experiments and Modelling of Water Injection in Soft Heavy Oil Reservoirs

2015 ◽  
Author(s):  
C.J.. J. de Pater ◽  
Matthieu Brizard
Keyword(s):  
Water Injection ◽  
Fracture Propagation ◽  
Numerical Data ◽  
Water Flooding ◽  
Two Phase ◽  
Unconsolidated Sands ◽  
Coupled Numerical Model ◽  
Heavy Oil Reservoirs ◽  
Matrix Flow ◽  
Minimum Stress

Abstract Water flooding is often applied to increase the recovery of oil from reservoirs. In practice, the water injectivity below the fracture propagation pressure (at so called matrix flow), is usually too low, so that the pressure is increased and the well is fractured. The fracture behavior is however different for unconsolidated sands than for consolidated rock as higher pressures relative to the minimum stress are required to obtain fracture propagation. Injecting water at higher pressure will lead to higher recovery. Our aim was to gain experimental and numerical data to establish the transition from matrix flow to fracturing. We present a series of model tests on different unconsolidated materials using large cylindrical samples with a diameter of 0.4 m. We changed the permeability of the sample and investigated the effect of cohesion by adding cement to some of the samples. It appeared that fractures obtained in material without any cohesion are really complex. On the other hand, adding some small cohesion to the sample, we observed a fracture more like “classical” fractures in competent rocks. For interpreting the tests, we have developed a fully coupled numerical model taking into account the two phase flow of oil and water, and the deformation of the sample.

Experimental Study and Pore Network Modeling of Formation Damage Induced by Fines Migration in Unconsolidated Sandstone Reservoirs

2020 ◽  
Vol 142 (11) ◽  
Author(s):  
Xiaodong Han ◽  
Liguo Zhong ◽  
Yigang Liu ◽  
Tao Fang ◽  
Cunliang Chen
Keyword(s):  
Water Injection ◽  
Three Dimensional ◽  
Experimental Results ◽  
Ion Concentration ◽  
Formation Damage ◽  
Fluid Viscosity ◽  
Pore Scale ◽  
Reservoir Properties ◽  
Reservoir Permeability ◽  
Sandstone Reservoirs

Abstract Fine migration is always considered as one of the major mechanisms that are responsible for formation damage. The unwanted reduction of reservoir permeability would result in the decline of water injection and consequent oil production, especially for the unconsolidated sandstone reservoir. For better understanding, the mechanisms of formation damage in pore-scale, a new three-dimensional pore-scale network model (PNM) is proposed and developed to simulate formation damage caused by particle detachment, migration, and capture in pore throats based on force analysis. Experiments are also conducted on the formation damage characteristics of an unconsolidated core. Both X-ray diffraction and scanning electron microscope (SEM) are applied to understand the microscopic reservoir properties. The experimental results show that the studied core has a strong flowrate sensitivity. A comparison between experimental results and PNM simulation results is conducted. The simulated results agree well with the experimental data, which approves the efficiency and accuracy of the PNM. Sensitivity analysis results show that larger particle sizes, higher flowrate, higher fluid viscosity, and lower ion concentration of the fluids would contribute to the formation damage, which could provide guidance for the development of unconsolidated sandstone reservoirs with strong sensitivity.

An Experimental Investigation of Fracture Propagation During Water Injection

2002 ◽  
Author(s):  
Roberto Suarez-Rivera ◽  
Jørn Stenebråten ◽  
Phani B. Gadde ◽  
Mukul M. Sharma
Keyword(s):  
Experimental Investigation ◽  
Water Injection ◽  
Fracture Propagation

New method of controlling excessive water production in wells using induced formation damage

2015 ◽  
Vol 55 (2) ◽  
pp. 485
Author(s):  
Abbas Zeinijahromi ◽  
Pavel Bedrikovetski
Keyword(s):  
Fresh Water ◽  
Large Scale ◽  
Produced Water ◽  
Water Injection ◽  
Cost Effective ◽  
Formation Damage ◽  
Water Production ◽  
Permeable Barrier ◽  
Water Influx ◽  
Excessive Water

Excessive water production is a major factor in reduced well productivity. This can result from water channelling from the water table to the well through natural fractures or faults, water breakthrough in high permeability zones, or water coning. The use of foams or gels for controlling water production through high-permeable layers has been tested successfully in several field cases. A large treatment volume, however, is required to block the water influx that generally involves high operational and material costs. This extended abstract proposes a new cost-effective method of creating a low-permeable barrier against the produced water with induced formation damage. The method includes applying induced formation damage to block the water influx without hindering the oil production. This can be achieved by injection of a small slug of fresh water into the water-producing layer. This results in release of in situ fines from the matrix, which can decrease permeability and create a local low-permeable barrier to the producing water. In large-scale approximation, water injection with induced fines migration is analogous to polymer flooding. This analogy is used to model the fresh water with induced formation damage. Sensitivity studies showed that the injection of 0.01 PVI of fresh water resulted in the blockage of the water-producing layer and an incremental recovery by 8% in field case A, with respect to the standard production scenario. The authors found that the incremental gas recovery with induced formation damage was sensitive to reservoir heterogeneity, permeability reduction and slug volume.

Injectivity formation damage due to fines migration

2018 ◽  
Vol 58 (2) ◽  
pp. 700
Author(s):  
Larissa Chequer ◽  
Mohammad Bagheri ◽  
Abbas Zeinijahromi ◽  
Pavel Bedrikovetsky
Keyword(s):  
Analytical Model ◽  
Water Injection ◽  
Laboratory Data ◽  
Formation Damage ◽  
Fines Migration ◽  
Low Salinity ◽  
Low Salinity Water ◽  
Damaged Zone ◽  
Salinity Water ◽  
Low Salinity Water Injection

Formation damage by fines migration during low-salinity water injection can greatly affect field-scale waterflooding projects. In this paper, we present the basic governing equations for single-phase flow with detachment, migration and straining of natural reservoir fines. We perform laboratory corefloods with low-salinity water injections and monitor the breakthrough particle concentration and pressure drop across the core. The analytical model for linear flow matches the laboratory data with high accuracy. The analytical model for radial flow predicts well behaviour from laboratory-tuned coefficients. The calculations show that fines migration during low-salinity water injection causes significant injectivity decline. For typical values of fines-migration model coefficients, injectivity index declines 2–8 times during 10−3 pore volumes injected and the radius of the damaged zone does not exceed a few metres. We present two field cases on waterflooding and low-salinity water injection. The radial model presents good agreement with well injectivity field data.

Fracture Propagation and Injector Performance Predictive Model During Produced (Dirty) Water Injection

2006 ◽  
Author(s):  
Karim S. Zaki ◽  
Manoj Dnyandeo Sarfare ◽  
Ahmed S. Abou-Sayed ◽  
Laurence Roderick Murray
Keyword(s):  
Predictive Model ◽  
Water Injection ◽  
Fracture Propagation ◽  
Dirty Water
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