Anisotropy of volume change and permeability evolution of hard sandstones under triaxial stress conditions

Menezes, Flora Feitosa

doi:10.1016/j.petrol.2018.11.079

Cited by 21 publications

(7 citation statements)

References 31 publications

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“…В Пермском крае значительно возросла доля разрабатываемых нефтяных активов, относящихся к карбонатным сложнопостроенным объектам. Карбонатные сложнопостроенные коллекторы характеризуются различными типами пустотности (поры, трещины, каверны), значительной неоднородностью, перетоками флюидов между типами пустот, а также различием между латеральной и вертикальной проницаемостью, данные факторы в значительной мере влияют на продуктивность и производительность добывающих скважин и в целом на коэффициент нефтеизвлечения [1,11,14,16]. Достоверное знание параметров трещинно-порового типа коллектора позволяет уточнить действующие геолого-гидродинамических модели (ГГДМ), подобрать рациональную систему разработки, отрегулировать процессы разработки и обеспечить оптимальные геолого-технические мероприятия (ГТМ) для данного пласта [5,10,13].…”

Section: совершенствование геолого-гидродинамической модели карбонатного нефтяного объекта путем учета параметра анизотропии проницаемостunclassified

Improving the geological and hydrodynamic model of a carbonate oil object by taking into account the permeability anisotropy parameter

Martyushev

2020

PMI

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Significant share of the developed oil assets related to carbonate complex-built objects has formidably increased in Russia, including the Perm Region. Reliable knowledge of the parameters for the cavern-pore type of the reservoir allows clarifying the existing geological and hydrodynamic models (GHM), selecting a rational development system, regulating the development processes and providing optimal geological and technical measures for this formation. In the construction and adaptation of GHM for oil fields, especially those related to complex-built carbonate reservoirs, knowledge of both horizontal and vertical permeability (anisotropy parameter) is important. When creating GHM of carbonate objects in Perm Region deposits, vertical permeability is often taken to be zero, although this is far from being the case. Determining the vertical permeability (anisotropy parameter), its dynamics when changing the formation and bottomhole pressures and using it in GHM is an urgent task that will improve the quality and reliability of using digital models to calculate and predict the oil production process. Article describes the methodology for determining permeability anisotropy according to the interpretation of hydrodynamic investigations of wells. Proposed methodology for determining the anisotropy parameter processed the results of more than 200 studies conducted on production and injection wells of the Famennian deposit at the Gagarinskoye field. For each lithological-facies zone, dependence of the permeability anisotropy index on the bottomhole pressure is constructed. To predict and evaluate the effectiveness of the applied geological and technical measures and technological development indicators, author modified the geological and hydrodynamic model taking into account the obtained dependencies on the change in the anisotropy parameter. Using a modified hydrodynamic model, it was possible to significantly improve the adaptation of both production and injection wells. Thus, the quality and reliability of the digital model of the Famennian deposit at the Gagarinskoye field for calculating and predicting the oil production process has improved.

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Improving the geological and hydrodynamic model of a carbonate oil object by taking into account the permeability anisotropy parameter

Martyushev

2020

PMI

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“…Numerous permeability prediction models have been developed on the basis of MIP and NMR parameters. The Swanson model, Pittman model, and Purcell model, for instance, are based on relationships between permeability and pore parameters determined by MIP, while the Schlumberger-Doll Research (SDR) and Coates model use the NMR data. − …”

Section: Introductionmentioning

confidence: 99%

“…Well testing, core analysis, and well logging are the most common methods to measure reservoir rock permeability. However, all these methods are expensive and time-consuming, so there is a need for cheap and effective alternatives for estimating rock permeability. , Since the pore structure is commonly thought to influence the permeability through pore size distribution (PSD) and pore connectivity, − predicting permeability by means of correlations to pore structure parameters has gained prominence in formation evaluation, particularly in unconventional reservoirs with extremely complicated pore structures. Nuclear magnetic resonance (NMR) and mercury injection porosimetry (MIP) are two commonly used methods for assessing the pore characteristics of porous media, and both of them can be performed on cutting samples .…”

Section: Introductionmentioning

confidence: 99%

New Model for Absolute Permeability Prediction in Coal Samples: Application of Modified Purcell Model to Mercury Injection Pressure and Nuclear Magnetic Resonance Data

Chang

Zhang

2023

ACS Omega

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The permeability of rocks is a critical parameter in many subsurface geological applications, and pore properties measured on rock samples (including rock fragments) can be used to estimate rock permeability. A major use of MIP and NMR data is to assess the pore properties of a rock in order to estimate the permeability based on empirical equations. Although sandstones have been extensively studied, permeability in coals has received less attention. Consequently, in order to obtain reliable predictions for coal permeability, a comprehensive study of different permeability models was performed on coal samples having a range of permeabilities from 0.003 to 1.26 mD. The model results showed that the seepage pores in coals account for the bulk of the permeability, while the contribution of adsorption pores to permeability is negligible. The models that only consider a single pore size point on the mercury curve, such as the Pittman and Swanson model, or those that use the entire pore size distribution, like the Purcell and SDR model, are inadequate for predicting permeability in coals. This study modifies the Purcell model to determine permeability from the seepage pores of coal, resulting in the enhancement of the predictive capability, with an increased R 2 and reduction in the average absolute error by approximately 50% compared to the Purcell model. To apply the modified Purcell model to NMR data, a new model was developed that provides a high degree of predictive capability (∼0.1 mD). This new model can be used for cuttings, which could lead to a new method for field permeability estimation.

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“…In the past few years, many experimental studies have studied the permeability of various types of rocks during the triaxial seepage stress process, including high-strength granite [5,6], low-strength sedimentary rock [7], and sandstone with high porosity [8][9][10]. These results provide an important reference for further understanding the mechanisms by which strength and porosity affect rock permeability.…”

Section: Introductionmentioning

confidence: 99%

Experimental Study on Permeability Evolution of Sandstone during Triaxial Compression Damage

Wei,

Lin,

Long

et al. 2023

Applied Sciences

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In order to investigate the mechanical properties and permeability characteristics of sandstone during damage evolution under hydromechanical condition, a series of coupled hydro-mechanical triaxial tests on sandstone specimens were conducted based on the Rock Top 50HT full-stress multi-field coupling triaxial test system. Variations in permeability as a function of confining pressure, seepage pressure gradient, and volumetric strain during damage evolution were obtained. The results show that: (1) When the confining pressure is constant and the specimen is gradually changed from a dry to a saturated state, the failure mode of sandstone changes from shear failure to single-slope shear failure. (2) There are four distinctive stages in the permeability evolution of sandstone: gradual decrease, steady development, gradual increase, and rapid growth. These stages correspond to the complete stress–strain curve under the respective working conditions. (3) Employing the Weibull distribution formula, this study investigates the evolution of fracture damage under varying working conditions and determines the permeability evolution relationships associated with damage variables. This exploration reveals an intrinsic link between permeability and damage variables. These findings enhance our understanding of the interplay between stress, deformation, permeability, and damage evolution in seepage-stress coupled sandstone. The results contribute valuable insights to the field of rock mechanics and hold implications for diverse geotechnical and engineering applications.

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Anisotropy of volume change and permeability evolution of hard sandstones under triaxial stress conditions

Cited by 21 publications

References 31 publications

Improving the geological and hydrodynamic model of a carbonate oil object by taking into account the permeability anisotropy parameter

Improving the geological and hydrodynamic model of a carbonate oil object by taking into account the permeability anisotropy parameter

New Model for Absolute Permeability Prediction in Coal Samples: Application of Modified Purcell Model to Mercury Injection Pressure and Nuclear Magnetic Resonance Data

Experimental Study on Permeability Evolution of Sandstone during Triaxial Compression Damage

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