With years of collective experience in geoscience software, our skilled scientists and technicians have served the industry’s leading companies over the past 30 years. Here, their knowledge is shared to help clients. Discover new insights and get a better understanding of your reservoir dynamics. Expand your GeoSoftware expertise with our Tips & Tricks.
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AVO modeling tools can sometimes be overwhelming for simple modeling and synthetic studies. HampsonRussell gives you an intuitive AVO modeling technique that helps build blocky models either from table input, or from rock physics Petro Elastic Models. To see AVO modeling in action, keep reading.
If you'd like to learn more about how this tool can help your understanding of reservoir reconnaissance work, send an email to our regional contacts, or request an evaluation copy of our software.
The specified layer models, thickness and amplitude, can be edited interactively and the response on the AVO synthetics and AVO curves is updated in real time (Figures 1 and 2).
Figure 1. Definition of a 3-layer Ostrander model with two shales with a middle gas sand
Figure 2.1 & Figure 2.2: Interactive layer editing to study of the effects of parameter changes
Figure 3.1 & Figure 3.2: The ability to use Petro Elastic Models (PEMs) in 1D AVO modeling adds a layer of flexibility that makes the tool even more powerful. This feature is available in HampsonRussell RockSI™ and supports the specification of more complex rock physics models.
2D and 3D modeling options, including wedge, anticlinal and dipping layer models, were introduced in HampsonRussell 10.2. Send an email to our regional contacts, or request an evaluation of our software to see these new tools in real time.
Reservoir Characterization is a challenging but critical process for Geoscientists. Here are some of the issues our clients have encountered:
The GeoSoftware Reservoir Characterization tool kit addresses these problems using HampsonRussell RockSI™, GeoSI and Emerge. The objective in this interpretation phase is to convert the elastic properties from seismic inversions to volumes of reservoir properties such as porosity, fluid saturation or clay volume.
By combining quantitative interpretation with qualitative analysis we can now provide a relative estimation of hydrocarbon-in-place. This provides crucial information for identifying appropriate drilling locations and well paths to optimize proven reserves and production in the project area. Below is a suggested workflow.
To see these tools in action, watch the presentation here, or read the brief summary below.
First, use RockSI™ to better understand and honor the impact of the target reservoir parameter variations within the study area; reservoir parameter changes such as variation in effective pressure, aspect ratio, mineral volumes or fluid type can be modeled.
Then use GeoSI to produce elastic properties with higher detail to better image thin layers or compartmentalization, and obtain the detailed 3D litho-facies volumes focused on the target reservoir. Probability analysis of the litho-facies and a probabilistic connectivity analysis of the reservoir bodies as defined by the preferred litho-facies can also be obtained.
Finally, use Emerge to convert the detailed elastic property volumes and associated litho-facies probabilities from GeoSI to reservoir properties such as porosity, fluid saturation or clay volume.
Start orchestrating Your Solutions with the HampsonRussell Analysis Tool Kit and improve your reservoir characterization. Visit our website to request a free software evaluation.
PowerLog is the benchmark for petrophysics, rock physics, facies analysis and statistical mineralogy. As a multi-user, multi-well, multi-interpreter software, PowerLog is tuned for flexible petrophysical workflows. Using PowerLog you will be able to properly calculate a modeled Vp & Vs curve from mineral volume and well data within our RPM Module.
In this example, we will be focusing on our Differential Effective Medium Models where we will be establishing our Vp with respect to our aspect ratio. Having this piece of information, as well as a host of others, are essential to calculate our velocities.
The necessary information for the workflow can be broken into two main categories based on where you get them. PowerLog excels at calculating pressure, temperature, water saturation, etc. However, information such as Grain-Pore Structure you will need to get from prior knowledge of your region of interest.
For this particular project we will need prior knowledge on the Gulf of Mexico. The image below is the raw data of the zone we are focusing on.
The workflow that is covered in this Tips and Tricks was developed by one of our top rock physicists; If you’d like to use this workflow in one of your projects, contact GeoSoftware support and ask for the DEM workflow.
To better understand the workflow we have broken it down into color coded windows and nodes. The yellow nodes are the major inputs necessary for this workflow to function. We will be going over them in minor detail after going over where to place the inputs.
The green boxes contain not only inputs but known constants that are needed for this information, and can be changed to fit your needs at your own discretion.
The red boxes with the round nodules are the outputs for the entire module. These nodules are composed of all of the links that connect to them and can easily be followed back to their sources.
In the Fluid Property Inputs, you will need to have curves or constants appropriate for your particular project. Double click on each node and the input can be placed in the Parameters section. Also, you will need to put the new curve name in the designated block if you wish to have an output. It is not necessary for you to do so at this point, however if you feel the need to see these curves then you do need to create an output name.
The Petrophyiscal Inputs are all values that are calculated within PowerLog itself. We have multiple modules that will calculate Water Saturation, Total Porosity, & Clay Volume in the same step. The HINDEX curve represents the locations of hydrocarbon in your well.
The P-Sonic, S-Sonic and Density curves must come from the well itself. Without these three curves it’s not possible to use this workflow. There are a few options if you do not have these curves however, but will be dependent on the data you have available.
The DTS Shale Trend for Clay, and DTP Shale Trend for Clay Moduli are unique inputs; they can be either curves or constants and the choice is up to you. If your project is using a working constant you can define it here, however PowerLog allows you to create a varying set of values if required. If you believe that you have a system with a constant then you can assign it as such but if you want to have a varying set of values PowerLog allows you to create that.
These nodes run equations that are programed within RPM. Some of them also have the capability of being manipulated within the node.
These nodes are categorized as follows:
It is essential to use the calculated mineral volumes in our calculations for the modeled velocities. The effects of the minerals can be substantial on the values of those curves. If you have a system with more minerals you simply need to add them.
Now that we’ve gone through all of the preceding nodes we can now get to the final outputs.
The final outputs for the workflow are modified Vp, Vs and Density curves as shown below. These curves take into account our well and mineral data. They can now be used to further your knowledge of your reservoir and what it holds.
