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# Geomechanics of Compressibility – Part I: Why Is It Important?

After encountering frequent misunderstandings of rock compressibility and its applications, I decided to write a series of posts on ‘geomechanics of compressibility’ to explain its rock mechanical definition, its different types, methods of compressibility measurement and their differences and the parameters affecting this property especially stress path and hysteresis. As an introductory post, let’s start with explaining why compressibility is important to us. But wait a moment! If you feel the equations are eyesores just ignore them, I don’t think it will really matter.

**Fluid Flow Analysis**

Pore volume compressibility (*Cp*) has long been recognized as an important factor in __fluid flow simulation for aquifers and reservoirs__ as shown by the following fundamental equation of fluid flow in porous media:

*(**Cp**+**Cl**)**ρφ ∂p**/**∂t**+**∇**.**(**-**k**/**μ**(**∇p**+**ρg∇z**)**=**q *

*[In this equation, Cl is fluid compressibility, ρ is pore fluid density, φ is rock porosity, g is gravity acceleration, q is the source term, k is permeability, t is time and z is the elevation measured in the vertical direction oriented downward.]*

Figure 1. An old but popular graph based on laboratory tests used for estimation of rock compressibility for fluid flow analysis in reservoirs. (source: Hall, 1953).

Generally, in either of fluid flow simulations or material-balance calculations, the role of pore volume compressibility coefficient (*Cp*) becomes increasingly important __as the fluid compressibility decreases__. The importance of pore volume compressibility is even __more crucial for closed systems__ where, in absence of fluid flux, fluid flow and pressure changes are controlled mainly by pore volume changes.

**Hydrocarbon Reserve Estimation and Storage Capacity Evaluation**

Figure 2. Assessment of potential CO2 storage in United States (Source: www.epa.gov)

Pore volume compressibility is also important in __volumetric estimation of hydrocarbon reserves__(find more in here) and __evaluation of fluid storage capacity and efficiency in aquifers__ (for instance, waste fluid disposal or *CO2* sequestration). As a simple example, in estimation of storage capacity of closed-system aquifers, the efficiency factor (*Ei*) for storage is introduced by Zhou et al. (2008) as:

*Ei**=**(**Cp**+**Cw **)**Δp*

*[where Cw is the compressibility of water and Δp is the average pressure increase within the aquifer induced by injection.]*

**Approximation of Porosity Variation**

Another application of pore volume compressibility is for the __estimation of porosity change induced by pore pressure__ variation within a reservoir. The following equation is widely used for porosity approximation of consolidated and cemented reservoir rocks (e.g., Satter et al., 2008):

*φ**2**=**φ**1** **exp**(**Cp**(**p2**-**p1**)**)*

*[where φ1 and φ2 are the values of porosity, at reservoir pressures of p1 and p2, respectively.]*

Such relations are the most simplistic way of involving geomechanics in fluid flow simulation. However, as it can bee seen in Figure 3, such relations must be used with the most caution as I will discuss it in detail later in this series.

Figure 3. Variation of porosity with two consecutive cycles of pore pressure change (injection/production) in a uniaxial pore volume compressibility test (UPVT) for a sample from a sandstone formation in Alberta, Canada (Source: Soltanzadeh, 2016).