Changes

In order to thoroughly discriminate the reservoir and non-reservoir lithology, the dataset should be derived into but not limited to the following properties[1]:  

In order to thoroughly discriminate the reservoir and non-reservoir lithology, the dataset should be derived into but not limited to the following properties[1]:  

# ''AI'' (acoustic impedance) = this property is sensitive towards the change in lithology and fluid content. Gas has the lowest AI as it is acoustically softer compared to water, whereas oil sits in between. As this property is directly affected by the change in compaction and/or diagenetic processes, its sensitivity decreases under specific circumstances and may be unable to differentiate between each lithology.  

# ''AI'' (acoustic impedance) = this property is sensitive towards the change in lithology and fluid content. Gas has the lowest AI as it is acoustically softer compared to water, whereas oil sits in between. As this property is directly affected by the change in compaction and/or diagenetic processes, its sensitivity decreases under specific circumstances and may be unable to differentiate between each lithology.  

AI=V_p*Rho

<math>AI = V_p * Rho</math>

# ''V_p/V_s'' (velocity ratio)= sensitive towards the change in fluid content even between wet and hydrocarbon bearing sandstones as Vp generally drops due to the presence of gas or oil however, the Vs does not affected much and therefore will produce low Vp/Vs. Velocity ratio is mathematically defined as follow:  

# ''V_p/V_s'' (velocity ratio)= sensitive towards the change in fluid content even between wet and hydrocarbon bearing sandstones as Vp generally drops due to the presence of gas or oil however, the Vs does not affected much and therefore will produce low Vp/Vs. Velocity ratio is mathematically defined as follow:  

V_p/V_s=V_p/V_s  

V_p/V_s=V_p/V_s