A multivariate analysis may be used to correlate seismic attributes for a subterranean formation with petrophysical properties of the subterranean formation and/or microseismic data associated with treating, creating, and/or extending a fracture network of the subterranean formation. For example, a method may involve modeling petrophysical properties of a subterranean formation, microseismic data associated with treating a complex fracture network in the subterranean formation, or a combination thereof with a mathematical model based on measured data, microseismic data, completion and treatment data, or a combination thereof to produce a petrophysical property map, a microseismic data map, or a combination thereof; and correlating a seismic attribute map with the petrophysical property map, the microseismic data map, or the combination thereof using the mathematical model to produce at least one quantified correlation, wherein the seismic attribute map is a seismic attributed modeled for the complex fracture network.

A computing device can use a support vector machine to categorize well data as being associated with a noise event or a microseismic event. For example, the computing device can determine well data based on sensor signals from a sensor in a wellbore. The computing device can then use the support vector machine to categorize the well data as being associated with a noise event or a microseismic event.

A method for developing or maintaining a subterranean field includes: parameterizing seismic wave records for each identified seismic event to provide a parameter describing each seismic wave record used to identify each seismic event; generating a reference seismic event data base having the identified seismic events and the parameter; calculating a similarity value for new received seismic wave records with respect to each seismic event in the reference seismic event data base using the corresponding parameter to provide a plurality of similarity values; identifying a maximum similarity value from any of the similarity values in the plurality of similarity values that meets or exceeds a similarity threshold value; identifying a new seismic event at a location of the seismic event in the reference seismic event data base corresponding to the maximum similarity value; and modifying operation of subterranean field-related equipment in response to identifying the new seismic event.

The invention relates to a method for processing seismic images containing a reference trace and a control trace. During said method, a reference level and a recording level are defined. Then, the control trace is transformed on the reference level by means of a velocity model. A portion of the reference trace including the recording level is transformed by means of a current velocity model. A portion of the transformed control trace including the recording level is corrected by means of the current velocity model. Finally, an optimized current velocity model is determined.

Method and system for ongoing monitoring for underground structure at or near a production wellpad is provided. The system includes a sparse acquisition grid and utilizes information obtained from Rayleigh waves to monitor subsurface structures.

The present disclosure provides a technique for marine seismic imaging that processes data acquired from two or more different seismic surveys in a combined manner to advantageous effect. The different seismic surveys may use seabed sensors at same positions on the seabed, but they may have different shot locations and may be performed at different times. In one use case, the technique may be used to image a subsurface location that is difficult to image using either survey alone. In another use case, the technique may be used to image a subsurface location under an obstruction. The technique may also be utilized to efficiently monitor a reservoir over time.

Techniques for evaluating hydrocarbon reserves using tool response models are provided. An example method includes measuring a first fluid distribution of a first formation proximate to a first wellbore and measuring a second fluid distribution of a second formation proximate to a second wellbore. The method further includes generating a first tool response model for the first formation based at least in part on the first fluid distribution and generating a second tool response model for the second formation based at least in part on the second fluid distribution. The method further includes comparing results of the first tool response model to results of the second tool response model to determine a fluid distribution difference between the first formation and the second formation and implementing a drilling command to alter drilling of one of the first and second wellbores based at least in part on the fluid distribution difference.

Systems and methods for estimating reservoir productivity as a function of depth in a subsurface volume of interest are disclosed. Exemplary implementations may: obtain subsurface data and well data corresponding to a subsurface volume of interest; obtain a parameter model; use the subsurface data and the well data to generate multiple production parameter maps; apply the parameter model to the multiple production parameter maps to generate refined production parameter values; generate multiple refined production parameter graphs; display the multiple refined production parameter graphs; generate one or more user input options; receive the one or more user input options selected by a user to generate limited production parameter values; generate a representation of estimated reservoir productivity as a function of depth in the subsurface volume of interest using visual effects; and display the representation.

A method is described for time-lapse seismic imaging that may include detecting moir patterns in seismic images generated from time-lapse seismic data and identifying geologic features based on the moir patterns. The method may be executed by a computer system.

Microseismic-event data can be corrected (e.g., to reduce or eliminate bias). For example, a first distribution of microseismic events that occurred in a first area of a subterranean formation can be determined. The first distribution can be used as a reference distribution. A second distribution of microseismic events that occurred in a second area of the subterranean formation can also be determined. The second area of the subterranean formation can be farther from an observation well than the first area. The second distribution can be corrected by including, in the second distribution, microseismic events that have characteristics tailored for reducing a difference between the second distribution and the first distribution.