Abstract: Predicting sand production in a wellbore. A first set of characteristics is determined for a formation in the wellbore, wherein determining uses a plastic model of the formation, and wherein the first set of characteristics comprises a yield surface, a failure surface, a stress total strain, an elastic strain, and a plastic-strain relationship. A relationship among a second set of characteristics of the wellbore is determined using an effective stress model, wherein the second set comprises a drawdown pressure, a production rate, pore pressure, a temperature and a viscosity of a fluid in the wellbore, a fluid flow pressure in the wellbore, a drag force of fluid flow in the wellbore, and a type of fluid flow in the wellbore. A critical total strain is determined for the formation using the first set of characteristics and the relationship. The critical total strain is calibrated using a thick wall test.

Abstract: A method for estimating hydrocarbon volume in a layered subsurface formation includes determining a vertical resistivity and a horizontal resistivity in the formation. A bound water saturation and a total porosity of individual layers of the formation are determined. Values of horizontal resistivity and vertical resistivity of the formation are calculated based on the bound water saturation and the total porosity for each layer and on an estimated irreducible bulk volume of water in each layer. The estimated values are compared to the determined horizontal resistivity and vertical resistivity. The estimated irreducible water saturation in each layer is adjusted and estimating the values is repeated until differences between the estimated values and the determined vertical and horizontal resistivity values fall below a selected threshold. The hydrocarbon volume is estimated from the adjusted irreducible water saturation for each layer.

Abstract: A method of managing a fluid or gas reservoir is disclosed which assimilates diverse data having different acquisition time scales and spatial scales of coverage for iteratively producing a reservoir development plan that is used for optimizing an overall performance of a reservoir.

Abstract: The method for suppressing noise in the controlled seismic source electromagnetic survey data based on the frequency content of the noise (51) contained in the data. The invention recognizes that some data variations across bins cannot be attributed to resistivity variations within the earth. This variation across the bins constitutes a model of noise in such surveys, and the invention mitigates noise that obeys this model.

Abstract: A method is disclosed for assessing uncertainty comprising: creating a catalog for uncertainty areas; capturing quantitative and qualitative uncertainty data; establishing dependencies between uncertainties; associating risks to uncertainties; associating action plans and tasks to risks; creating a realization tree from uncertainty ranges; and tracking changes to uncertainties and realizations over time.

Abstract: A hybrid evolutionary algorithm (“HEA”) technique is described for automatically calculating well and drainage locations in a field. The technique includes planning a set of wells on a static reservoir model using an automated well planner tool that designs realistic wells that satisfy drilling and construction constraints. A subset of these locations is then selected based on dynamic flow simulation using a cost function that maximizes recovery or economic benefit. In particular, a large population of candidate targets, drain holes and trajectories is initially created using fast calculation analysis tools of cost and value, and as the workflow proceeds, the population size is reduced in each successive operation, thereby facilitating use of increasingly sophisticated calculation analysis tools for economic valuation of the reservoir while reducing overall time required to obtain the result. In the final operation, only a small number of full reservoir simulations are required for the most promising FDPs.

Abstract: A reservoir simulator first estimates rock displacement parameters (u, v, and w) representing rock movement in the x, y, and z directions. When the rock displacement parameters (u, v, w) are determined, “?x,y,z” (the ‘x,y,z elongation strains’) and “?xy,yz,xz” (the ‘shear strains’) are determined since “?x,y,z” and “?xy,yz,xz” are function of “u”, “v” and “w.” When “?x,y,z” and “?xy,yz,xz” are determined, “?x,y,z” (the ‘elastic normal rock stress in x,y,z directions’) and “?xy,yz,xz” (the ‘elastic shear stress’) are determined since “?x,y,z” and “?xy,yz,xz” are a function of “?x,y,z” and “?xy,yz,xz”. When “?x,y,z” and “?xy,yz,xz” are determined, the rock momentum balance differential equations can be solved, since these equations are a function of “?x,y,z” and “?xy,yz,xz”. When any residuals are substantially equal to zero, the estimated rock displacement parameters (u, v, and w) represent ‘accurate rock displacement parameters’ for the reservoir.

Abstract: A method for detecting hydrocarbons includes obtaining seismic trace data for a region of interest; and processing the seismic trace data to calculate a Smooth Signal Spectrum for each of a plurality of locations in the region of interest. A system for detecting hydrocarbons includes a processor and a memory, wherein the memory comprises a program having instructions for: obtaining seismic trace data for a region of interest; and processing the seismic trace data to calculate a Smooth Signal Spectrum for each of a plurality of locations in the region of interest.

Abstract: The invention relates to a method of estimating the flow restart conditions of a paraffinic hydrocarbon in a pipe, wherein the following stages are carried out: selecting a theological model, determining the temperature and shear stress fields in the steady hydrocarbon flow, evaluating the conductive thermal exchanges during circulation standstill phases, from the steady flow temperatures and the standstill time taken into account, selecting various sections of the pipe and recording the thermomechanical scenarios undergone by the hydrocarbon in these sections, experimentally measuring the rheological parameters of the model on a sample of the hydrocarbon, according to each one of said scenarios, and taking into account these experimental measurements to evaluate the value of the pressure that restarts circulation of the paraffinic hydrocarbon in the pipe.

Abstract: Method for predicting lithology and porosity of subsurface rocks from seismic reflection data. The seismic data is inverted to yield elastic properties of the rocks such as the compressional and shear impedances. A rock physics model is built to relate porosity, the shale volume fraction, the fluid content of the rock and the elastic properties of the rock. The model is run backward in a second inversion process to solve for porosity and lithologic properties such as the shale volume fraction.

Abstract: The present disclosure presents illustrative embodiments of a method for estimating the producibility of a hydrocarbon bearing formation using a flexural mechanical resonator to measure the viscosity and density of a representative fluid from the formation. A system is disclosed for estimating the producibility of a hydrocarbon bearing formation using a flexural mechanical resonator to measure the viscosity and density of a representative fluid from the formation. A data structure is disclosed for storing data useful for estimating the producibility of a hydrocarbon bearing formation using a flexural mechanical resonator to measure the viscosity and density of a representative fluid from the formation. The data structure provides a structural and functional interrelationship between the data structure, data in the data structure and a computer and computer software provided in an illustrative embodiment.

Abstract: A process for constructing a three-dimensional geologic model of a subsurface earth volume wherein resolution scales of multiple diverse data types, including seismic data, are accounted for by generating multiple frequency passband models and combining them together to form the complete geologic model. Preferably, a model is generated for each of a low-frequency passband, a mid-frequency passband, and a high-frequency passband. When integrating seismic data into the modeling process, the seismic-frequency passband constitutes the mid-frequency passband model. The process further contemplates updating tentative frequency-passband models through optimization of assigned rock property values in each tentative model according to specified geological criteria. Such optimization is carried out by perturbation of the rock property values in a manner wherein the frequency content of each model is maintained.

Abstract: Methods and systems are provided for evaluating subsurface earth oil and gas formations. More particularly, methods and systems are provided for determining reservoir properties such as reservoir transmissibilities and average reservoir pressures of formation layer(s) using quantitative refracture-candidate diagnostic methods. The methods herein may use pressure falloff data from the introduction of an injection fluid at a pressure above the formation fracture pressure to analyze reservoir properties. The model recognizes that a new induced fracture creates additional storage volume in the formation and that a quantitative refracture-candidate diagnostic test in a layer may exhibit variable storage during the pressure falloff, and a change in storage may be observed at hydraulic fracture closure.

Abstract: A method, practiced by a Hydraulic Fracturing Simulator software, is adapted for simulating a hydraulic fracture in an Earth formation, the formation including a plurality of layers, a slip zone, which represents a debonding between adjacent layers of the Earth formation, possibly existing between the adjacent layers, the method comprising the step of: setting up an Influence Coefficient Matrix, the matrix having a plurality of numbers, the plurality of numbers of the Influence Coefficient Matrix being calculated and determined such that the method, practiced by the Hydraulic Fracturing Simulator software for simulating the hydraulic fracture, will model, or take into account an existence of, the slip zone and/or the debonding between the adjacent layers of the Earth formation.

Abstract: Systems and methods are disclosed to construct subsurface images from diffuse seismic energy. Various disclosed system embodiments include multiple seismic sensors that each convert received seismic energy into one or more seismic signals. One or more processor combine the seismic signals to determine a subsurface map. As part of determining the map, the processor(s) systematically focus the array of seismic sensors on each bin in the subsurface volume of interest. In this manner each bin becomes a focal point of the array. For each bin, the processor(s) analyze the seismic wave travel time to each seismic sensor and apply a corresponding time shift to align the seismic signals with a uniform travel time. The time-shifted seismic signals are then combined to determine an intensity value for seismic energy radiating from the focal point. A subsurface map can then be derived from the intensity value as a function of position.

Abstract: The present invention is a method of generating a model of a random field which has directionally varying continuity. First, a tentative model for the random field is specified. Second, connected strings of nodes within the model are identified. Third, a spectral simulation on each of the strings of nodes is performed to determine updated values for the random field. Finally, the tentative model is updated with the data values from the spectral simulations.

Abstract: A method for enhancing allocation of fluid flow rates among a plurality of wellbores coupled to surface facilities is disclosed. The method includes modeling fluid flow characteristics of the wellbores and reservoirs penetrated by the wellbores. The method includes modeling fluid flow characteristics of the surface facilities. An optimizer adapted to determine an enhanced value of an objective function corresponding to the modeled fluid flow characteristics of the wellbores and the surface facilities is then operated. The objective function relates to at least one production system performance parameter. Fluid flow rates are then allocated according to the optimization.

Abstract: Techniques for estimating the fraction of water in formations being investigated use measurements of dielectric permittivity at a number of frequencies. The techniques have the advantage of minimizing or eliminating external inputs that can introduce inaccuracies.

Abstract: Method and system are disclosed for determining hydrocarbon CDVs in a multiphase environment. The method and system involve calculating a total hydrocarbons volume from an apparent oil volume and an apparent gas volume. The apparent oil volume is determined using C/O data from a nuclear logging tool operating in inelastic neutron scattering mode. The apparent gas volume is determined using neutron porosity data from a nuclear logging tool operating in pulsed neutron capture (“PNC”) mode. It is also possible to determine the total hydrocarbons volume using log data from formation thermal neutron capture cross section measurements, or a cased hole formation resistivity tool. The total hydrocarbons volume is then used to back-calculate the total hydrocarbons CDV at various formation depths using the logged C/O data. The resulting independently calculated total hydrocarbon CDV may be used for proper matching of log data and simulation results for history matching purposes.

Abstract: A method for simulating compositional and/or multiphase transfers between the porous matrix and the fractures of a fractured multilayer porous medium, which are respectively saturated by a distinct liquid phase and gas phase. The method comprises constructing a geologic model representative of the networks of natural fractures of the medium and converting this geologic model into an equivalent double porosity model. Diffusion of the gas phase between the fractures and the matrix is modelled considering that a gas-liquid front exhibiting a quasi-static equilibrium at the interfaces is established from an initial time and progresses at a velocity controlled by the diffusion transfers within each phase. The transfers involve the difference between the concentration within the phase and the concentration of equilibrium between the two phases, as well as a variable exchange distance expressed as a function of the matrix saturation.

Abstract: The disclosure is directed to a computer-implemented method of representing fluid flow in a physical fluid reservoir. The method includes generating a mesh representation of the physical fluid reservoir having a plurality of mesh elements. Each of the plurality of mesh elements is representative of a regional portion of the fluid reservoir. The method further includes generating a matrix-based representation of fluid flow comprising matrix elements associated with a mesh element and selectively weighting the matrix elements based on fluid flow direction in the regional portion of the fluid reservoir represented by the mesh element associated with the matrix element.

Abstract: A closed-loop circulating system for drilling wells has control of the flow rates in and out of the wellbore. Kicks and fluid losses are quickly controlled by adjusting the backpressure. Kick tolerance and tripping margins are eliminated by real-time determination of pore and fracture pressure. The system can incorporate a rotating BOP and can be used with underbalanced drilling.

Abstract: Methods for processing pyrolytic characterizing data (pcd) from reservoir rock samples obtained from known geographical locations under circumstances that are encountered during the drilling of wells provide information that is important for assessing the relative amounts of various hydrocarbon and organic matter types found in the reservoir and for characterizing the reservoir quality and preparing compositional modeling data, and include the steps of comparing the pcd for known end-member components typically found in the geographical location with the pcd derived from test samples and applying mathematical analyses to identify the predicted composition and quantitative measure of end-members. The method is applied to model hydrocarbon moveability, reservoir injectivity; contaminants and soil an aquifer pollutants.

Abstract: Various methods are disclosed for evaluating water saturation characteristics in a geological formation penetrated by a borehole, including injection fluid introduced into the formation by an external injection process performed upon the formation. In various embodiments, the total water saturation may be obtained from the relationship provided by the Triple Water Equation, and used to map saturation in the formation and making drilling decisions.

Abstract: Techniques for determining formation characteristics use measurements of dielectric permittivity at a number of frequencies. Determined characteristics include the vertical and horizontal formation dielectric constant and conductivity, the formation water conductivity, the water saturation, the cementation and the saturation exponents. In laminated formations these profiles can be determined for each lamina. Also, formation dielectric properties are used in determination of the rock type.

Abstract: Pre-drill pore pressure and fracture gradient predictions obtained from seismic velocity data are used in well design taking into account uncertainties in the velocity estimation and in the models that use the velocities to determine pore pressure. Using geological constraints, limits are established on hydrocarbon column height. It is also possible to predict the relative number of casings required to reach target reservoirs.

Abstract: A method for forming a model simulating production, by an underground reservoir subject to depletion, of hydrocarbons comprising notably relatively high-viscosity oils. From laboratory measurements of the respective volumes of oil and gas produced by rock samples from the reservoir subject to depletion, and the relative permeabilities (Kr) of rock samples to hydrocarbons, a model of the formation and flow of the gas fraction is used to determine a volume transfer coefficient (hv) by means of an empirical function representing the distribution of nuclei that can be activated at a pressure P (function N(P)) which is calibrated with reference to the previous measurements.

Abstract: A method of seismo electromagnetic detecting of hydrocarbon deposits has the steps of simultaneously initiating an electromagnetic field and a seismic wave in investigated geological region so that an electromagnetic signal originates by vibrating of hydrocarbon deposit surface excited by the electromagnetic field and travels from the surface, recording the electromagnetic signal together with transient electromagnetic process in the region, and making a conclusion about a hydrocarbon deposit based on the recorded electromagnetic sign together with the transient electromagnetic process.

Abstract: The invention is a method for simulating one or more characteristics of a multi-component, hydrocarbon-bearing formation into which a displacement fluid having at least one component is injected to displace formation hydrocarbons. The first step of the method is to equate at least part of the formation to a multiplicity of gridcells. Each gridcell is then divided into two regions, a first region representing a portion of each gridcell swept by the displacement fluid and a second region representing a portion of each gridcell essentially unswept by the displacement fluid. The distribution of components in each region is assumed to be essentially uniform. A model is constructed that is representative of fluid properties within each region, fluid flow between gridcells using principles of percolation theory, and component transport between the regions. The model is then used in a simulator to simulate one or more characteristics of the formation.

Abstract: Methods and systems are provided for downhole analysis of formation fluids by deriving fluid properties and associated uncertainty in the predicted fluid properties based on downhole data, and generating answer products of interest based on differences in the fluid properties. Measured data are used to compute levels of contamination in downhole fluids using an oil-base mud contamination monitoring (OCM) algorithm. Fluid properties are predicted for the fluids and uncertainties in predicted fluid properties are derived. A statistical framework is provided for comparing the fluids to generate, in real-time, robust answer products relating to the formation fluids and reservoirs thereof. Systematic errors in measured data are reduced or eliminated by preferred sampling procedures.

Abstract: A lumping and delumping method is useful for estimating the properties or behavior of liquid and/or vapor hydrocarbon phases from data relative to a reference set of hydrocarbon mixtures in a series of thermodynamic states in a medium. Each one of the hydrocarbon mixtures is grouped into at least three constituents (V, I, H), considering that the gas phases resulting from separation under conditions referred to as surface conditions of each mixture do not contain (H) and that the oil phases do not contain (V). The compositions of the separation products are determined by material balance. The at least three-constituent composition of each hydrocarbon mixture is determined by combination of the products resulting from the separation in proportion to the amounts of each separation product. Delumping is performed to predict a detailed composition of a fluid in the medium.

Abstract: A method for prospecting for oil and gas deposits is provided, said method comprising: outlining of highly permeable collecting basins development zones, performing an aerospace survey of a landscape, determining a spectral reflectivity over the landscape, and incorporating the height profile, block fields, aerospace survey and spectral relativity in order to produce a predictiveis provided.

Abstract: Measurements made with porosity and density logging tools in a gas reservoir may differ due to invasion effects. The effects are particularly large on measurement-while-drilling applications where invasion is minimal. Using a Monte-Carlo method, a relationship is established between true formation porosity and porosity estimates from density and porosity tools. This relationship is used on real data to get an improved estimate of formation porosity and of gas saturation.

Abstract: A closed-loop circulating system for drilling wells has control of the flow rates in and out of the wellbore. Kicks and fluid losses are quickly controlled by adjusting the backpressure. Kick tolerance and tripping margins are eliminated by real-time determination of pore and fracture pressure. The system can incorporate a rotating BOP and can be used with underbalanced drilling.

Abstract: A technique is described for interpretation of IPTT tests. In one implementation, the technique may be configured or designed to standardize the complete interpretation procedure of IPTT in a heterogeneous reservoir, using if available, modern wireline logs (such as, for example, nuclear magnetic resonance and imaging), dynamic data from wireline formation testers and/or any other relevant information (such as, for example, geological description, core data and local knowledge) as constraints on the interpretation. Additionally, an iterative method may be used to define formation layering. An advanced regression technology may also be used to obtain optimized horizontal and vertical permeabilities of reservoir layers.

Abstract: A method of managing multiple wells connected to a reservoir comprises the steps of: setting production and performance goals for each individual well; monitoring the performance of each individual well; enabling each individual well to assess its own situational state; and enabling socially interactive corrective actions, comprising enabling collaboration and cooperation among the wells, such that the wells share with each other their situational states, goals, and plan data; developing and refining remediation strategies for problems detected within the wells; allowing execution of the remediation strategies either independently, or by operator intervention; applying the remediation strategies to each individual well; revising and resetting the goals, and integrating pattern recognition and machine learning within all preceding steps.

Abstract: The present invention relates to a method of evaluating the hydraulic potential of a porous stratum defined between two depths zlow and zhigh, the method consisting in generating periodic modulation in the rate of flow from the well, in lowering down the well and in activating for a few periods at the depth zlow a measuring PLT sonde, in extracting from the resulting measurements the amplitude ?Qlow of the sinusoidal component of the flow rate modulation relating to one of the imposed periods T, the amplitude ?Plow of the sinusoidal component of the pressure modulation relating to the same period T, and the phase delay of the pressure sinewave relative to the flow rate sinewave ?low, in determining the response R low = ? ? ? P low ? ? ? Q low ? ? - ?? low in raising the sonde to depth zhigh, and in determining the complex response R high = ? ? ? P high ? ? ? Q low ? ? - ? ? ? ? high in calculating the complex response

Abstract: A method for stimulation of hydrocarbon production via imbibition by utilization of surfactants. The method includes use of fuzzy logic and neural network architecture constructs to determine surfactant use.

Abstract: A control system and method for determining optimal fluid injection pressure is based upon a model of a growing hydrofracture due to waterflood injection pressure. This model is used to develop a control system optimizing the injection pressure by using a prescribed injection goal coupled with the historical times, pressures, and volume of injected fluid at a single well. In this control method, the historical data is used to derive two major flow components: the transitional component, where cumulative injection volume is scaled as the square root of time, and a steady-state breakthrough component, which scales linearly with respect to time. These components provide diagnostic information and allow for the prevention of rapid fracture growth and associated massive water break through that is an important part of a successful waterflood, thereby extending the life of both injection and associated production wells in waterflood secondary oil recovery operations.

Abstract: Disclosed herein are systems and methods of hydrocarbon detection based on wavelet energy absorption analysis. One disclosed hydrocarbon detection method embodiment includes: a) obtaining seismic trace data for a region of interest; and b) processing the seismic trace data to determine at least one wavelet energy absorption factor as a function of position within the region of interest. Another disclosed hydrocarbon detection method embodiment includes: a) receiving from a user an indication of a region of interest in a seismic data set; and b) generating a display of wavelet energy absorption anomalies within the region of interest. One of the disclosed system embodiments includes a memory and a processor. In this system embodiment, the memory stores hydrocarbon detection software that, when executed by the processor, configures the processor to determine at least one wavelet energy absorption factor from seismic trace data.

Abstract: Production of a well is predicted by associating log profiles for wells in a reservoir to production indicators for wells in the reservoir. A log for the well is matched to a corresponding log profile. The log profiles may each be generated by clustering logs for wells in the reservoir. The log profiles and logs may include magnetic resonance imaging (MRI) and/or other suitable data.

Abstract: A method for inferring production of a rod pumped well. Inferred production is estimated in a well manager which not only performs pump-off control with a down-hole pump card, but also estimates liquid (oil-water) and gas production using the subsurface pump as a meter. Methods are incorporated in the well manager for identifying and quantifying several conditions: pump leakage, unanchored tubing, free gas and oil shrinkage. Quantifying such conditions in the well manger enables accurate inferring of production thereby eliminating the need for traditional well tests.

Abstract: A method for designing a closed-chamber drillstem test system. Parameters of available equipment and a well to be tested are collected. Initial or proposed chamber size and chamber pressurizing fluids are then selected. A simulation of a test is then performed. The simulation is performed in time increments, with pressure in the well assumed to be static during each time increment. Calculated flow volume from the formation during each increment is used to adjust pressure in the well for the next increment. The process is continued until the test would be considered complete based on an optimization parameter. If the total simulated time to complete the test is not in a desirable range, the initial chamber parameters are changed and the simulation is run again. The process is repeated until the simulated test time reaches a desirable range.

Abstract: A method of analyzing results from an underwater controlled source electromagnetic (CSEM) survey of an area that is thought or known to contain a subterranean hydrocarbon reservoir is described. The method is based on a wavefield extrapolation of narrow-band electromagnetic field data obtained from pairs of source and receiver locations. The data comprise a plurality of discrete frequencies between 0.01 Hz and 60 Hz. The wavefield extrapolation is performed for each of these discrete frequencies to provide distributions of electromagnetic scattering coefficient as a function of position and depth beneath the survey area. These distributions may then be combined to provide a displayable image of electromagnetic scattering coefficient. The method is able to quickly provide a displayable image that is readily interpretable.

Abstract: A process to determine optimal completion type and design prior to drilling of a hydrocarbon producing well utilizing information from hydrocarbon recovery modeling such as reservoir, geo-mechanical, and material modeling over the production life of the well. An embodiment of the process includes obtaining information regarding pore pressure depletion, stress magnitudes and orientations, and strength of rock formation from hydrocarbon recovery modeling to determine optimum well completion design including the selection of a completion type, trajectory, and location. Additionally, the process may also consider probable failure mechanisms and identified completion requirements, and their corresponding effect on completion options.

Abstract: A method designed to combine both pseudo compressional interval velocity and pseudo shear interval velocity from seismic data for predicting fluid type and porosity in oil and gas exploration. The first step is the generation of ?S, pseudo shear reflectivity data, and P, pseudo compressional reflectivity data from the seismic data. The second step of the method is to produce scaled pseudo shear reflectivity ?Vs and scaled pseudo compressional reflectivity ?Vp from both the ?S and P data and then combine and re-project the ?Vs and the ?Vp data. The compression and shear reflectivity data are inverted, scaled to pseudo-velocity and then calibrated to well control. The resulting ?Vp and ?Vs volumes produce fluid volume and porosity volume. The fluid and porosity volumes can be stored in an electronic storage medium for analysis to distinguish between commercial and non-commercial gas accumulations prior to drilling.

Abstract: The present invention is a method of interpreting sampled mud gas compositional and isotopic data from a target area in a drilling operation. The compositional and isotopic data is plotted on a chart. The chart preferably illustrates methane compositional data together with isotopic composition, such as ?13C1. From this chart, mixing lines are determined. The mixing lines are determined by finding data points plotted on the chart which approximate a straight line or other trend. The mixing lines are then analyzed to determine reservoir isotopic signature, hydrocarbon communication and any interference to this communication within the target area.

Abstract: A method of determining fluid flow in a volume containing two or more fluid components, including determining a pressure field for the volume. One or more streamlines are determined from the pressure field, and the fluid composition is solved for the fluid composition along the, or each, streamline. The pressure may also be solved along the, or each, streamline. The step of solving along the, or each, streamline may be performed using a finite difference technique.

Abstract: The application of SET for the imaging and analysis of seismic energy emission induced during production of fluid resources from their reservoirs allows 4 dimensional measurements of the components of the permeability field of the reservoir. The seismic energy emission associated with the permeability field is identified by its spatial and temporal location with respect to a well or plurality of wells in which fluid pressure is being changed. Changing fluid pressure causes seismicity to rapidly migrate outward from the points of fluid pressure change and will alter the characteristics of the seismic energy emission. Monitoring the changes in seismic energy emission in response to pressure changes in the active well and altering the values of the processing parameters permits measurement of components of the permeability tensor. The placement of subsequent infill, development and injection wells may be selected based on the analysis.

Abstract: A method of interpreting mud gas samples in a drilling operation of a target area. The method starts with obtaining a plurality of mud gas samples at a plurality of incremental depths of the target area. The plurality of mud gas samples are analyzed to find various isotopic data at each depth. The isotopic data of the mud gas samples are plotting on several charts to provide a visual representation of the isotopic data trends. The charts may include: depth versus ethane/methane; depth versus ?13C per mil; and depth versus ?13C and gas show. In addition, the percentage methane versus ?13C is provided on a separate chart. This percentage methane versus ?13C chart provides engineering and geological information such as the location of lithological hydrocarbon seals, barriers, and zones of good hydrocarbon communication (e.g., compartments). This engineering and geological information is then correlated with the other charts.