Incompressive cake filtration: Mechanism, parameters, and modeling

Civan, Faruk

doi:10.1002/aic.690441106

Cited by 42 publications

(15 citation statements)

References 13 publications

Supporting

Mentioning

Contrasting

Order By: Relevance

“…For the static conditions, these stresses are totally neglected. Based upon the mass balance equation for the solid particles, the cake thickness can be written as follows (Civan, 1998(Civan, , 2000Parn-Anurak, 2003;Parn-Anurak and Engler, 2005;Civan, 2007):…”

Section: Cake Formationmentioning

confidence: 99%

See 1 more Smart Citation

On the filtrate drilling fluid formation and near well-bore damage along the petroleum well

Ramézani

Akkal

Cohaut

et al. 2015

Journal of Petroleum Science and Engineering

View full text Add to dashboard Cite

Section: Cake Formationmentioning

confidence: 99%

“…The flow rate is calculated based upon the Forchheimer's equation given by (Civan, 1998(Civan, , 2007: inertia coefficient for the filter-cake, respectively.…”

Section: Cake Formationmentioning

confidence: 99%

On the filtrate drilling fluid formation and near well-bore damage along the petroleum well

Ramézani

Akkal

Cohaut

et al. 2015

Journal of Petroleum Science and Engineering

View full text Add to dashboard Cite

“…However, Bahrami et al (2012) mention that filtrate invasion problems occur in naturally fractured shale reservoirs, but the weak-mud-cake formation on the wellbore and low porosity and strong capillary suction conditions allow for a prolonged liquid invasion over a long distance from the wellbore into the reservoir formation, and therefore, filter cake lifting is not really an issue of importance during the cleanup period. Filter-cake and pore blockage effects are discussed in detail elsewhere (Civan and Engler, 1994, Civan, 1998a,b, 2007a.…”

Section: Hydraulic-fluid Leakoff and Invasionmentioning

confidence: 99%

Analyses of Processes, Mechanisms, and Preventive Measures of Shale-Gas Reservoir Fluid, Completion, and Formation Damage

Civan

2014

SPE International Symposium and Exhibition on Formation Damage Control

Self Cite

View full text Add to dashboard Cite

A comprehensive review and modeling of the natural and induced fluid, completion, and formation damage processes and their governing mechanisms involving the various aspects of gas-bearing shale reservoir formations is presented. The damage potential of shale formations containing large quantities of clay and nonclay inorganic, and organic materials, and natural fractures filled with cement and other debris is delineated. The thermal, chemical, and stress interactions between the drilling and fracturing fluids and shale formations are described. The relevant processes and their fundamental mechanisms, including under/over balanced drilling, fracturing-fluid disposition and detainment, wettability and nonequilibrium fluid transport and spontaneous imbibitions, swelling and fluidization, and gas and water blockage occurring in extremely-low permeability shale porous media are reviewed. The critical review presented here provides valuable insights into the nature of the shale-gas reservoir formation damage, indicating the significant roles of the different orders of magnitude rate processes and the thermal, chemical, and stress shocks causing formation damage during drilling, completion, and production. The significant differences observed between the rates of adverse processes can be facilitated to effectively control, minimize, and/or prevent the common shale-gas reservoir production problems. The scientifically-guided protocol provided concerning the fluid, completion, and formation damage processes can help in effective mitigation of the flow assurance problems associated with hydraulically-fractured wells completed in gas-bearing shale reservoirs to maximize the well productivity.

show abstract

“…Even no other fluids is injected, the variations of pressure and temperature also bring about the formation damage through the interaction between various minerals and fluids, such as paraffin and asphaltene deposition (Wang and Civan, 2005). A few phenomenological models have been proposed to describe formation damage caused by water sensitivity, fine particles, and etc (Civan, 1998). Another interesting topic is involved in the wormhole formation Fogler, 1998, 1999;Szymczak and Ladd, 2009).…”

Section: Introductionmentioning

confidence: 99%

Mechanisms of reservoir pore/throat characteristics evolution during long-term waterflooding

Wang

Han

Dong

et al. 2017

Adv. Geo-Energ. Res.

View full text Add to dashboard Cite

Formation pore structure and reservoir parameters change continually during waterflooding due to sand production, clay erosion, and pressure/temperature variation, which causes great challenge in geological modeling and simulation. In this work, the XA Oilfield, a block with more than 20 years' waterflooding history, is used as an example to better understand the fundamental evolution mechanisms of reservoir pore network characteristics over long time waterflooding. We performed a large number of core analyses and experiments to obtain formation parameters (e.g., permeability, porosity, relative permeability, and etc.) at different development stages. The comparison illustrates that reservoir permeability can not only decrease with clay plugging, but also increase by the detachment of fine particles and even the destruction of microscopic structure. We also observed that the point/line contacts among grains decreases, the pore network connectivity increases, the clay content reduces and the rock trends to be more hydrophilic with increasing water injection. Moreover, we developed a pore network model to simulate the variation of formation parameter. The model parameters are also compared and analyzed to get a qualitative understanding of the evolvement laws, which will provide a useful guidance for reservoir accurate modeling.Keywords: Reservoir parameter variation, permeability, water flooding, pore network model, core analysis.Citation: Wang, S., Han, X., Dong, Y., et al. Mechanisms of reservoir pore/throat characteristics evolution during long-term waterflooding.

show abstract

Incompressive cake filtration: Mechanism, parameters, and modeling

Abstract: Improved models developed verify interpretation and prediction of incompressible fil

Cited by 42 publications

References 13 publications

On the filtrate drilling fluid formation and near well-bore damage along the petroleum well

On the filtrate drilling fluid formation and near well-bore damage along the petroleum well

Analyses of Processes, Mechanisms, and Preventive Measures of Shale-Gas Reservoir Fluid, Completion, and Formation Damage

Mechanisms of reservoir pore/throat characteristics evolution during long-term waterflooding

Contact Info

Product

Resources

About