Received 16 July 2016; accepted 16 August 2016; published 19 August 2016
Gas hydrate is a potential future energy resource in which huge quantity of methane gas is trapped as guest molecule in water molecule   . These unconventional energy resources are found at continental margin and permafrost  . Gas hydrates have different distribution and occurrence patterns, for example they may exist as a part of host sediments and part of fluids  . Usually gas hydrates are inferred on seismic section by a strong reflector known as bottom simulating reflector (BSR)  -  .
Since last decade, seismic attenuation and velocity dispersion gained a reasonable attention to explore gas hydrates reservoir   . The seismic attenuation in hydrate-bearing sediments depends largely on the distribution pattern of hydrates. Pecher and Holbrook  described that when gas hydrates are part of solid, they will cause an increase in seismic attenuation, but Rosi  negated their suggestions and recommended that when gas hydrates are part of solid, they may decrease seismic attenuation. Interpretation of sonic wave form data from Mackenzie (Canada) shows that seismic attenuation increases with the presence of gas hydrates-bearing sediments  . Vertical seismic profile data from Malikwell (Canada) show a strong attenuation response for gas hydrate saturated sediments  . In contrary, Matsushima  and Sain  concluded that when gas hydrates are part of solid they will incredibly stiffer host sediments, which is the major cause of decrease in attenuation with gas hydrate concentration. Li  endorsed the attenuation results of Sain  by doing numerical simulation for gas hydrates bearing sediments in Shenhu area of China. All above-mentioned researchers underestimate the attenuation phenomena for gas hydrates-bearing sediments when gas hydrates are considered part of formation fluid.
The Makran offshore of Pakistan has a large potential of gas hydrates   . Ehsan  studied the seismic and elastic properties as a function of gas hydrates saturation and distribution patterns. They studied these properties without considering seismic attenuation and velocity dispersion. In the present study, seismic wave attenuation and velocity dispersion phenomena are used to discriminate gas hydrates and free gas zones from water saturated sediments in Makran offshore of Pakistan. Location map of study area has shown in (Figure 1). The behavior of P wave velocity for gas layer at low frequency is nearly a straight line after certain saturation limit  . It is essential to find out the technique which will differentiate accurately reservoir saturation zone at low frequency domain. So we tried to implement seismic attenuation technique to sort out gas layer and gas hydrates saturation zone. A fruitful effort is made by Khalid and Ahmed  to understand the phenomenon of velocity dispersion and attenuation in partially saturated reservoirs. The velocity dispersion and attenuation in gas hydrates-bearing sediments of Makran offshore are studied under wave induced fluid flow (WIFF) mechanism at mesoscopic scale  and effective medium theory  .
2. Work Flow and Methodology
In order to elaborate variation in elastic properties such as saturated bulk modulus of gas hydrates and gas- bearing sediments in uniform and patchy distribution patterns, we have used two approaches: Gassmann-Wood and Gassmann-Hill in two frequency domains i.e. low and high respectively   . At low frequency patch,
Figure 1. Location map of Makran offshore area Pakistan   .
size is smaller than wave length and seismic wave has enough time for pore pressure equilibration. We have used Wood’s average  or Reuss’s average approach  to compute bulk modulus of gas hydrate/water and gas/water layer at low frequency regime  .
In the above equation, Xw and Xh are the saturation of water and hydrate. In order to compute response of bulk modulus for gas layer at low frequency, we simply alter Xh by Xg. We have used effective medium theory and modified form of Gassmann’s equation  to compute saturated bulk modulus for gas hydrates/water and gas/water layer at low frequency regime
In the above equation, is the accumulative bulk modulus of fluid at low frequency and Kdry is the bulk modulus of dry sediments, Km is accumulative bulk modulus of minerals and is the porosity of rock matrix. P wave modulus at low frequency limit (Psat0) for gas hydrates and gas-bearing sediments is given below.
In Equation (7) µ is shear modulus of dry sediments. In our modeling we have considered gas hydrates as a part of fluid so shear modulus of dry sediments equal to shear modulus of saturated sediments.
P wave velocity (α0) at low frequency regime (relaxed state) is given as
In order to compute velocity dispersion (variation of seismic wave velocity in porous medium with respect to frequency) and attenuation for gas hydrates and gas bearing sediments in Makran offshore area of Pakistan. The input parameters derived from Equations (1)-(4), the attenuation and velocity dispersions can be modeled by using equations described below  .
Further the relative variation in Psat and α which can be computed as  .
When higher frequencies seismic wave propagates through gas hydrates-bearing sediments or gas saturated layer, the wave length of seismic wave is smaller than patch size. Thus, the stiffness of pore fluid increased and cause an increase in velocity dispersion. We have used Ehsan  and Hill  methodology to compute seismic response of gas hydrates-bearing sediments.
Our main goal of this study is to understand the effect of elastic properties on velocity dispersion and attenuation for gas hydrates-bearing sediments, when they occurred as a part of fluid. The input parameters used in this numerical modeling are given in Table 1. The P wave velocity difference for gas hydrates-bearing sediments computed by GW (low frequency) GH approaches presented in (Figure 2) as a function of gas hydrates saturation. Previous study made by Ehsan  shows that the P wave velocity in low frequency regime is lower than of high frequency regime. At extreme points (Sh ~ 0 and Sh ~ 1.0) where pores are fully saturated with single fluid, the velocity dispersion is zero whereas at 0 < Sh > 1.0 both approaches give different values of velocity. The maximum velocity difference is attained at Sh ~ 0.66 where velocity difference is up to 50 m/s. This difference can be seen on high resolution seismic data in the form of velocity dispersion.
Table 1. Parameters used for numerical simulation to compute seismic attenuation and velocity dispersion (Ehsan et al., 2015  ).
Figure 2. Velocity difference plot against gas hydrates saturation for GW and GH approach.
Similarly, the velocity dispersion, when fluid distribution pattern depart from homogenous to patchy saturation, in partially gas-saturated sediments as a function of gas saturation (Sg) is demonstrated in the (Figure 3). It has been observed that the GW method underrate the seismic velocities. Stiffness of gas bearing sediments is much higher during patchy saturation. Velocity difference trend between lower frequency (Wood) and high frequency (Hill) domains shows totally different pattern from gas hydrate bearing sediments. Velocity difference (Δα) curve against gas saturation shows the maximum difference at low gas saturation (almost at 15%) and starts decreasing gradually as the gas saturation increases (Figure 3). In case of single fluid phase (100% water or gas saturation), both the approaches give similar results and therefore the velocity difference became zero.
In the (Figure 4(a) and Figure 4(b)), we have plotted the difference in elastic modului of fluids versus gas hydrates and gas saturation for both approaches (GW and GH) respectively. In case of gas hydrates-water case the maximum difference arise again at Sh ~ 66% (Sw ~ 34%), however in case of gas-water fluid phases, the maximum difference appears at low gas saturation (Sg ~ 15%).
In the Figure 4(a) shows that ΔKf for gas hydrate increases with increasing gas hydrate saturation. After 66% gas hydrate saturation ΔKf starts decreasing. In (Figure 4(b)), we have seen that ΔKf response for gas layer starts increasing with the increase of gas saturation, after 15% saturation, it starts decreasing. Now we have checked relative difference response of P wave modulus (ΔPsat/Psat∞) and velocity (Δα/α∞) for gas hydrate and gas
Figure 3. Velocity difference plot for gas saturated zone with GW and GH approach.
Figure 4. (a) Bulk modulus of fluids difference response for homogeneos and patchy distribution of gas hydrates bearing sediments (b) Bulk modulus of fluids difference response for homogeneos and patchy distribution of gas saturated sediments.
bearing saturated sediments. It is observed that at 0% and 100% of gas and gas hydrate saturation, relative difference of velocity and P wave modulus shows minimum response. It is clear from (Figure 5) that maximum difference of P wave modulus and velocity is obtained at 66% of gas hydrate saturation and 15% of gas saturation. It is clear from (Figure 5(a)) P wave modulus relative difference response and P wave velocity relative difference response for gas hydrates saturated sediments initially increase with increasing gas hydrates saturation and it will start decreasing after 66% gas hydrates saturation. Similar variation response is observed for gas saturated sediments in (Figure 5(b)).
3.1. Seismic Attenuation and Velocity Dispersion
In our previous discussion we have mentioned the variation in elastic properties for gas hydrates and gas saturation. Now we are trying to elaborate the imprints of these elastic properties to sort out their effects on seismic attenuation and velocity dispersion for gas hydrates and gas bearing sediments. The velocity dispersion and attenuation plots have been drawn at different saturations of gas hydrates in (Figure 6).
Velocity dispersion plots for different gas hydrates saturation versus water saturations are shown in (Figure 6(a)). In the (Figure 6(a)) lower extremity is representing homogeneous phase and upper extremity representing patchy phase. Here it is essential to mention that in case of patchy saturation, we have considered two patches, which are saturated with a symmetrical scheme, one patch saturated with water and other patch saturated with
Figure 5. (a) P wave modulus and velocity relative difference response for gas hydrate bearing sediments; (b) P wave modulus and velocity relative difference response for gas bearing sediments.
Figure 6. (a) Shows velocity dispersion response for gas hydrate bearing sediments at different saturation of gas hydrate bearing sediments; (b) It shows seismic attenuation for different gas hydrate saturated sediments.
gas hydrates. These patches assembled with each other in such a way that no fluid migrates from one patch to other patch. In (Figure 6(a)) we have plotted velocity dispersion for different gas hydrates saturation and maximum dispersion occurs at 66% gas hydrates. However, when sediments are fully saturated with gas hydrates (about ~0.99) little attenuation can be observed. Seismic attenuation and velocity dispersion are directly interlinked with each other. In (Figure 6(b)), we have checked attenuation response for WIFF at seismic frequency to sonic frequency range. We have elaborated that maximum velocity dispersion and attenuation take place at 66% saturation of gas hydrates. We have seen from our results, with increase of gas hydrates saturation, velocity dispersion and attenuation also increased, when they are part of fluid. These phenomena of increasing attenuation with increase of gas hydrate saturation hold at certain limit of gas hydrates saturation; this certain limit is called characteristics saturation. After this characteristics saturation seismic attenuation decreases gradually.
The results reveal that when gas hydrates are part of fluid, seismic attenuation increase with increase in gas hydrates saturation until it will not reach at characteristics saturation limit. After this characteristics saturation the attenuation start to decrease.
We have also computed velocity dispersion and attenuation for gas saturated sediments as shown in (Figure 7). In (Figure 7(a)) velocity dispersion plots are computed for different gas saturation. Velocity dispersion plots
Figure 7. (a) Velocity dispersion plots for gas saturated zone in Makran offshore area Pakistan; (b) Seismic attenuation plots for gas saturated sediments.
show that maximum velocity dispersion for gas bearing sediments occurred at 15% gas saturation. Similarly maximum attenuation also obtained at 15% gas saturation as shown in (Figure 7(b)). Seismic attenuation and velocity dispersion is interrelated each other. In Figure 7(a) we have observed that maximum velocity dispersion is observed at 15% of gas saturation after this saturation velocity dispersion start decreasing. Similarly maximum attenuation is observed at 15% free gas saturation, after this saturation attenuation curves start decreasing with increasing gas saturation. Our all previous discussions elaborate attenuation and velocity dispersion for gas hydrate and gas bearing sediments shows that elastic properties of fluids and seismic response plays a vital role in attenuation and velocity dispersion phenomenon. We depicted that velocity difference Δα fluid difference ΔKf and relative difference curves for P wave velocity and P wave effective modulus interconnected directly with attenuation. Seismic attenuation is an important attribute to depict low saturated gas reservoir and medial saturated gas hydrated reservoir for Makran offshore area Pakistan.
Seismic attenuation and velocity dispersion are interconnected with elastic properties of gas hydrates and gas bearing sediments. Velocity difference, fluid modulus difference and relative difference in P wave modulus show maxima for gas hydrates and gas bearing sediments at 66% and 15% saturation. It is observed that when gas hydrates are part of fluid, seismic attenuation increases with increase of gas hydrate saturation, till characteristics saturation. After characteristics saturation, velocity dispersion and attenuation decrease for gas hydrate and gas bearing saturated zone. Seismic attenuation and velocity dispersion can be used as vital seismic attri- butes for the characterization of gas hydrates-bearing sediments and free gas saturated sediments for Makran offshore area Pakistan.