Abstract: A linear solver methodology is applied to reservoir data to solve for large system of equations arising from high-resolution reservoir simulation of giant oil fields with minimal upscaling using either structured grids or unstructured grids. Full geologic complexity and discontinuities at the resolution desired for accurate simulation results may be taken into account. A general unstructured method is provided, so that very complex flow geometry near multi-lateral wells can be modeled.

Abstract: In some aspects, sand stabilization treatments are analyzed. A computing system can determine a first predicted resource production output for a subterranean reservoir based on a sand stability model analysis for a native condition of the subterranean reservoir. The computing system can determine a second predicted resource production output for the subterranean reservoir based on a sand stability model analysis for a stabilization-treated condition of the subterranean reservoir. The computing system can output an economic value comparison of resource production for the native condition and the stabilization-treated condition based on the first and second predicted resource production outputs.

Abstract: Method for estimating the Hessian of the objective function, times a vector, in order to compute an update in an iterative optimization solution to a partial differential equation such as the wave equation, used for example in full wave field inversion of seismic data. The Hessian times vector operation is approximated as one forward wave propagation (24) and one gradient computation (25) in a modified subsurface model (23). The modified subsurface model may be a linear combination of the current subsurface model (20) and the vector (21) to be multiplied by the Hessian matrix. The forward-modeled data from the modified model are treated as a field measurement in the data residual of the objective function for the gradient computation in the modified model. In model parameter estimation by iterative inversion of geophysical data, the vector in the first iteration may be the gradient of the objective function.

Abstract: A method of enhancing a geologic model of a subsurface region is provided. A bed topography of the subsurface region is obtained. The bed topography is defined by a plurality of cells with an elevation associated with each cell center. The bed topography is represented as a cell-centered piecewise constant representation based on the elevations associated with the cells. The bed topography is reconstructed to produce a spatially continuous surface. Flux and gravitation al force-related source terms are calculated based on the reconstructed bed topography. Fluxes are calculated between at least two of the cells. Fluid flow, deposition of sediments onto the bed, and/or erosion of sediments from the bed are predicted using the fluxes and gravitational force-related source terms. The predictions are inputted into the geologic model to predict characteristics of the subsurface region, and the predicted characteristics are outputted.

Abstract: A polarized detection system performs imaging, object detection, and change detection factoring in the orientation of an object relative to the orientation of transceivers. The polarized detection system may operate on one of several modes of operation based on whether the imaging, object detection, or change detection is performed separately for each transceiver orientation. In combined change mode, the polarized detection system performs imaging, object detection, and change detection separately for each transceiver orientation, and then combines changes across polarizations. In combined object mode, the polarized detection system performs imaging and object detection separately for each transceiver orientation, and then combines objects across polarizations and performs change detection on the result.

Abstract: A hydrocarbon exploration method for determining subsurface properties from geophysical survey data. Rock physics trends are identified and for each trend a rock physics model is determined that relates the subsurface property to geophysical properties (103). The uncertainty in the rock physics trends is also estimated (104). A geophysical forward model is selected (105), and its uncertainty is estimated (106). These quantities are used in an optimization process (107) resulting in an estimate of the subsurface property and its uncertainty.

Abstract: A computer-implemented method for evaluating a geoscience data analysis question. The user inputs the question to the computer through a graphical user interface or a text command interface (11). The computer is programmed to derive a statistical measure for evaluating the question (12). One or more data elements (14) are inputted to the computer, and the derived statistical measure is applied to the data elements and computed (13).

Abstract: A method for determining properties of a formation comprises disposing at least one acoustic logging tool in a well and moving the logging tool along the well. An acoustic logging is performed during movement of the acoustic logging tool together with simultaneous thermal treatment of the formation. A temperature of a formation zone being thermally treated is measured as well as attenuation and velocity of the Stoneley waves excited by the acoustic logging tool. Based on the obtained dependencies of measured parameters as functions of the formation zone temperature formation relative phase permeabilities, formation fluid viscosity and viscous flow activation energy are determined.

Abstract: Method for generating a new family of seismic attributes sensitive to seismic texture that can be used for classification and grouping of seismic data into seismically similar regions. A 2D or 3D data analysis window size is selected (23), and for each of multiple positions (25) of the analysis window in the seismic data volume, the data within the window are transformed to a wavenumber domain spectrum (26). At least one attribute of the seismic data is then defined based on one or more spectral properties, and the attribute is computed (28) for each window, generating a multidimensional spectral attribute data volume (29). The attribute data volume can be used for inferring hydrocarbon potential, preferably after classifying the data volume cells based on the computed attribute, partitioning the cells into regions based on the classification, and prioritizing of the regions within a classification.

Abstract: Disclosed herein are various embodiments of methods and systems for determining the orientation and direction of first motion of a fault or fracture by optimizing an azimuthally-dependent attribute of signals generated by microseismic sources, comprising: recording microseismic data traces using a of sensors located at a plurality of sensor positions; subdividing the subsurface volume into spatial volumes corresponding to selected time intervals and comprising a plurality of voxels; for each voxel, applying a time shift to the microseismic data traces that is substantially equal to a travel time from each voxel to the corresponding sensor position, and determining for the voxel the orientation and direction of first motion of the fault or fracture corresponding to a maximum value for the voxel of at least one azimuthally-dependent attribute of the microseismic data traces.

Abstract: Techniques for calculating metrics for reservoir quality based on light oil and total organic carbon in tight oil reservoirs are described. The techniques include calculating quantities of light oil and total organic carbon from logging data and generating therefrom a continuous log for reservoir quality metric. Additionally new reservoir quality indices are presented that more accurately predict reservoir quality in tight oil plays.

Abstract: The invention relates to the development of an analytical model to predict the velocity of the continuously expanding front of the steam chamber in a steam assisted gravity drainage (SAGD) hydrocarbon production system. The developed analytical model has advantages over reservoir simulation tool in that it is very fast and can be easily calibrated with field observation well data before making good prediction. One field study shows that the developed model can achieve excellent prediction for a field SAGD performance. A better understanding of the size of the steam chamber and the velocity of the front should provide better time, cost and energy efficiency for the production of high viscosity hydrocarbons.

Abstract: Well production rate, injection rate and pressure data are measured in an existing reservoir using in situ real time measurement gauges. Production and injection rates are entered as input to a history match model in a data processing system. Measures of projected reservoir pressure with time are generated by running the updated history match model using a reservoir simulator. Actual reservoir data values obtained at a given date or time slice from reservoir production are compared with projected data obtained from the reservoir simulator for that same date or time slice. At each time slice, the real-time pressure values measured at the wellbore are converted into reservoir pressures through a well model. The real time reservoir pressure values and the projected reservoir pressure are then used to interpolate the reservoir pressure array over the entire three dimensions using a geostatistical modeling process.

Abstract: Methods for modeling a tight hydrocarbon reservoir intersected by a borehole. Methods include using an estimated hydrocarbons-in-place value for the tight hydrocarbon reservoir and a gas parameter associated with drilling the borehole to create a drilling model. The model may determine an operation of a well control device associated with the borehole; or correlate the hydrocarbons-in-place value with the gas parameter for the tight hydrocarbon reservoir. Other methods include determining, during the forming of the borehole, an operation of a well control device associated with the borehole using an estimated hydrocarbons-in-place for the tight hydrocarbon reservoir and a gas parameter. The gas parameter may comprise a detected gas parameter normalized using at least one corresponding drilling parameter. Further methods include employing the model for performing operations in another borehole drilled in the same reservoir.

Abstract: Disclosed dielectric logging tools and methods employ three or more receive horn antennas positioned between at least two transmit antennas, which can also be horn antennas. The logging tools can operate in the range between 100 MHz and 10 GHz to provide logs of formation permittivity, formation conductivity, standoff distance, and electrical properties of material in the standoff gap. Logs of water-saturated porosity and/or oil movability can be readily derived. The presence of additional receive antennas offers a significantly extended operating range, additional depths of investigation, increased measurement accuracy, and further offers compensation for tool standoff and mudcake effects. In both wireline and logging while drilling embodiments, at least some disclosed dielectric logging tools employ a set of three axially-spaced receive antennas positioned between pairs of axially-spaced transmit antennas.

Abstract: A method for mapping remaining hydrocarbon resources in a subsurface reservoir, includes generating a pressure depletion map of the subsurface reservoir based on a pressure depletion dataset representing a pressure change in at least one well over a time interval, obtaining a hydrocarbon pore thickness map of the subsurface reservoir based on a hydrocarbon pore thickness dataset representing hydrocarbon pore thickness substantially at a beginning of the time interval, using the pressure depletion map and the hydrocarbon pore thickness map, generating a remaining resource map of the subsurface reservoir, for each of a plurality of infill wells located in the subsurface reservoir and operated during a portion of the time interval, determining an estimated ultimate recovery value, using each estimated ultimate recovery value with data from the remaining resource map for the locations of the infill wells to determine a correlation, and using the correlations and the remaining resource map, evaluating a location f

Abstract: A methodology that performs fluid sampling within a wellbore traversing a reservoir and fluid analysis on the fluid sample(s) to determine properties (including asphaltene concentration) of the fluid sample(s). At least one model is used to predict asphaltene concentration as a function of location in the reservoir. The predicted asphaltene concentrations are compared with corresponding concentrations measured by the fluid analysis to identify if the asphaltene of the fluid sample(s) corresponds to a particular asphaltene type (e.g., asphaltene clusters common in heavy oil). If so, a viscosity model is used to derive viscosity of the reservoir fluids as a function of location in the reservoir. The viscosity model allows for gradients in the viscosity of the reservoir fluids as a function of depth. The results of the viscosity model (and/or parts thereof) can be used in reservoir understanding workflows and in reservoir simulation.

Abstract: Real-time method for determining the porosity and water saturation of an underground formation using gas and mud logging data A method and a computer program product for determining the porosity (PHI) and water saturation (Sw) of an underground formation while drilling a borehole, using gas and mud logging data obtained while drilling.

Abstract: Downhole tools and techniques acquire information regarding nearby conductors such as pipes, well casing, and conductive formations. At least some method embodiments provide a current flow along a drill string in a borehole. The current flow disperses into the surrounding formation and causes a secondary current flow in the nearby conductor. The magnetic field from the secondary current flow can be detected using one or more azimuthally-sensitive antennas. Direction and distance estimates may be obtainable from the azimuthally-sensitive measurements, and can be used as the basis for steering the drillstring relative to the distant conductor. Possible techniques for providing current flow in the drillstring include imposing a voltage across an insulated gap or using a toroid around the drillstring to induce the current flow.

Abstract: A method of estimating fluid composition in an earth formation includes: generating at least one pulsed neutron measurement by a pulsed neutron tool; estimating a pulsed neutron fluid saturation by analyzing the at least one pulsed neutron measurement via a pulsed neutron model of the earth formation, the pulsed neutron model including expected pulsed neutron measurements relative to selected fluid composition and properties; comparing the pulsed neutron fluid saturation to a reference fluid saturation estimated via a downhole tool; adjusting the pulsed neutron model to at least substantially eliminate a difference between the pulsed neutron fluid saturation and the reference fluid saturation by adjusting at least one of the selected fluid composition and the selected fluid properties; and estimating at least one of the fluid composition and the fluid properties based on the adjusted model.

Abstract: A method for stratigraphic analysis of seismic data comprises: selecting a seismic data volume comprising a plurality of samples; selecting a number of horizons within the seismic data volume; selecting a scale of interest within the seismic data volume, which ranges from 500 m up to the size of the entire seismic data volume; applying an attribute function to at least one of the selected number of horizons at the selected scale of interest; and displaying a stratigraphic attribute, which represents a geologic feature, such as a seismic facies attribute, an unconformity attribute and/or a thinning attribute that highlights a rate of thickness change of a formation layer between adjacent horizons, as a result of applying the attribute function at the selected scale of interest. These attributes facilitate understanding of moderate to large-scale seismic geometries (500 m to 50 Km) and basin development over geologic time.

Abstract: A method for water monitoring about a deviated well is disclosed. The method includes positioning a series of electromagnetic (EM) receivers in a completed deviated wellbore, said receivers being spaced along substantially the length of the well located in a region of a reservoir to be monitored. The method also includes positioning an electromagnetic (EM) source at a first Earth surface location. Then the EM source is activated for a first survey measurement of the reservoir, and an EM field detected at each EM receiver is recorded. The EM source is moved to a second Earth surface location, and activated for a second survey measurement of the reservoir, and an EM field detected at each EM receiver is recorded. From the first and second survey measurements at each of the receivers, an inversion is performed to determine position of water about (and specifically below) the horizontal well.

Abstract: Methods and systems are described for hydrocarbon production. One method embodiment of the invention comprises analyzing phases of hydrocarbon oil, gas and water at flowing conditions extracted from a hydrocarbon well; separating the oil, water and gas mixture into oil portions, water portions and gas portions, each respective portion being substantially only oil, water or gas; analyzing the separated oil portion and determining if the separated oil portion meets predetermined oil standards, and treating any separated oil portion that does not meet the oil standards to achieve those standards; transferring the oil portion meeting the predetermined oil standards to a predetermined destination; analyzing the separated water portion to determine if the water portion meets predetermined water standards and treating any separated water portion that does not meet the water standards to achieve those standards; and transferring the treated water portion meeting the predetermined standards to a destination.

Abstract: This description relates to computer simulation of physical processes, such as computer simulation of multi-species flow through porous media including the determination/estimation of relative permeabilities for the multi-species flow through the porous media.

Abstract: In some embodiments, a motion detecting device is configured to detect whether one or more movement events have occurred. The motion detecting device can include: (a) a processing module configured to run on a computational unit; and (b) a sensing device having: (1) one or more pressure sensors configured to provide two or more pressure measurements; and (2) a transmitter electrically coupled to the one or more pressure sensors and configured to transmit the two or more pressure measurements to the computational unit. The processing module is configured to use the two or more pressure measurements to determine whether the one or more movement events have occurred. The sensing device can be configured to be placed in at least one of ductwork of a heating, ventilation, and air conditioning system or an air handler of the heating, ventilation, and air conditioning system. Other embodiments are disclosed.

Abstract: Methods, systems, and apparatus for inducing fractures in a subterranean formation and more particularly methods and apparatus to place a first fracture with a first orientation in a formation followed by a second fracture with a second angular orientation in the formation are disclosed. The first and second fractures are initiated at about a fracturing location. The initiation of the first fracture is characterized by a first orientation line. The first fracture temporarily alters a stress field in the subterranean formation. The initiation of the second fracture is characterized by a second orientation line. The first orientation line and the second orientation line have an angular disposition to each other.

Abstract: Systems, methods, and devices are provided to determine an accurate neutron-gamma density (NGD) measurement for a broad range of formations, including low-hydrogen-index or low-porosity formations and formations with heavy elements. For example, such an NGD measurement may be obtained by emitting neutrons into a formation such that some of the neutrons inelastically scatter off elements of the formation and generate inelastic gamma rays. The neutrons and inelastic gamma rays that return to the downhole tool may be detected. Some characteristics of certain formations are believed to affect the fast neutron transport of the formations. Thus, if a formation has one or more of such characteristics, a correction may be applied to the count rate of neutrons, the count rate of inelastic gamma rays, or the neutron transport correction function, upon which the neutron-gamma density (NGD) may be determined.

Abstract: A method and computer-readable medium for determining a scattered wave particle velocity for a formation is disclosed. In aspects, the method may include: defining an embedded grid of the formation, and defining a contrast grid of the formation that includes a contrast feature of the formation; calculating a Green's function over the embedded grid; calculating a first scattering vector of the contrast feature for a first offset between the embedded grid and the contrast grid; determining the scattered wave particle velocity for the contrast feature at the first offset using the calculated Green's function and the first scattering vector; calculating a second scattering vector of the contrast feature for a second offset between the embedded grid and the contrast grid; and determining the scattered wave particle velocity for the contrast feature at the second offset is determined using the calculated Green's function and the second scattering vector.

Abstract: A method is disclosed for determining for determining a presence, type, quality and/or volume of a subsurface hydrocarbon accumulation from a sample related thereto. The method may include determining a noble gas signature of a sample and at least one or more of determining a clumped isotope signature of the sample and characterizing the ecology signature of the sample. Then, the method integrates signatures to determine information about the subsurface accumulation, such as the location, fluid type and quality, and volume of a subsurface hydrocarbon accumulation.

Abstract: Described herein are implementations of various technologies for a method. The method may receive seismic attributes regarding a region of interest in a subsurface of the earth. The method may receive electrical attributes regarding the region of interest. The method may receive a selection of a rock physics model for the region of interest. The method may calculate values of rock parameters for the selected rock physics model using a nonlinear relation that links cross-properties between the seismic attributes and the electrical attributes for the region of interest. The method may determine the presence of hydrocarbon deposits in the region of interest using the calculated values.

Abstract: Analysis evaluates formation fluid with a downhole tool disposed in a borehole. A plurality of possible constituents is defined for the formation fluid, and constraints are defined for the possible constituents. The constraints can include boundary constraints and constraints on the system's dynamics. The formation fluid is obtained from the borehole with the downhole tool over a plurality of time intervals, and density of the obtained formation fluid is obtained at the time intervals. To evaluate the fluid composition, a state probability distribution of the possible constituents of the obtained formation fluid at the current time interval is computed recursively from that at the previous time interval and by assimilating the current measured density of the obtained formation fluid in addition to the defined boundary/dynamic constraints.

Abstract: Various techniques for generating a polar display include a method, which involves receiving information identifying a formation property of an anomaly within a geologic formation from a measurement-while-drilling (MWD) tool that includes several sensors. The formation property is identified by at least one magnitude and at least one distance. The formation property is also identified relative to a corresponding property of the geologic formation. The method also involves receiving information identifying an azimuthal angle from the MWD tool, where the azimuthal angle relates a position of the anomalous formation to a position of a first sensor. The method then generates a graphic, based upon the at least one magnitude and the at least one distance and the azimuthal angle, and displays the graphic on a polar display, in which a center of the polar display corresponds to a location of the borehole in which the MWD tool is located.

Abstract: A system for creating a log during gas detection and monitoring is disclosed herein. The system can include a gas detection and well logging device for sensing and transmitting data, which can include a processor in communication with a monitoring device. The monitoring device can monitor, acquire, and transmit data associated with a drilling operation. The processor can receive the data, calibrate the data, and log the data into files. The processor can capture sensed data based on a time event and a depth event. The processor can scale the data and form a geological-hydrocarbon log for transmission. A client device can be in communication with the gas detection and well logging device, and can have computer instructions for querying the geological hydrocarbon log, the data, and the files to obtain real time streaming data for instant display.

Abstract: Methods for identifying hydrocarbon plays include applying predictive models to sediment fill volume(s) to provide play-element volume(s) representing at least one play element. Each play-element volume represents at least 1) qualities of the at least one play element and 2) a probability that the at least one play element satisfies determined criteria for each of a plurality of locations within a basin. The methods further include analyzing the play-element volume(s) to define play-concept volume(s) representing hydrocarbon play(s). Each of a plurality of locations within the play-concept volume(s) is attributed with: 1) an identification of each play element associated with the location, 2) the qualities of each play element, 3) the probability for each play element that it satisfies determined criteria, and 4) a composite likelihood that the location represents a hydrocarbon play. At least one of the volumes may be used to identify hydrocarbon play(s).

Abstract: A method for geological formation analysis may include collecting time-lapsed well-based measurement data from a first borehole in a geological formation over a measurement time period, and collecting time-lapsed electromagnetic (EM) cross-well measurement data via a plurality of spaced-apart second boreholes in the geological formation over the measurement time period. The method may further include determining simulated changes to a hydrocarbon resource in the geological formation over the measurement time period based upon a geological model using a processor, and using the processor to determine if the simulated changes are within an error threshold of the time-lapsed well-based measurement data and the time-lapsed cross-well EM measurement data. If the simulated changes are not within the error threshold, then the geological model may be updated.

Abstract: A method for efficient inversion of measured geophysical data from a subsurface region to prospect for hydrocarbons. Gathers of measured data (40) are encoded (60) using a set of non-equivalent encoding functions (30). Then all data records in each encoded gather that correspond to a single receiver are summed (60), repeating for each receiver to generate a simultaneous encoded gather (80). The method employs iterative, local optimization of a cost function to invert the encoded gathers of simultaneous source data. An adjoint method is used to calculate the gradients of the cost function needed for the local optimization process (100). The inverted data yields a physical properties model (110) of the subsurface region that, after iterative updating, can indicate presence of accumulations of hydrocarbons.

Abstract: Computer-implemented systems and methods are provided for generating corrected performance data of water flooding of an oil reservoir system based on application of a statistical correction factor methodology (SCF). For example, data related to properties of the oil reservoir system and data related to a water flooding scenario are received. Water flooding performance data is generated based on application of an analytical water flooding performance computation methodology. Based on application of the SCF methodology to the generated water flooding performance data, corrected water flooding performance data is determined, representative of oil recovery by the water flooding of the oil reservoir system. The SCF methodology can also be used to evaluate water production based on parameters such as water-oil ratio and water cut, identify possible analog reservoirs that have similar water production performance, and calculate a Gross Injection Factor to account for water loss in the reservoir.

Abstract: The invention provides a method of detecting seawater contamination from an offshore hydrocarbon well facility comprising seabed wellheads connected by hydrocarbon conduits to a seabed pipeline head from which a hydrocarbon pipeline leads to a remote hydrocarbon receiving facility, each said wellhead being provided with a protective cover to which is removably attached a sensor unit, each said sensor unit comprising a biological sensor and a data transmitter coupled by a data transmission line to said remote facility, said well facility further comprising a seawater velocity sensor, a seawater conductivity sensor and a temperature sensor also coupled by a data transmission line, wherein data from said data transmission line is analysed to determine indicia of seawater contamination at said well facility and of the seawater flow at said well facility and thereby to provide a signal indicative of seawater contamination above a preselected limit deriving from said well facility.

Abstract: The invention is a method of monitoring an underground formation into which a gas is injected or from which a gas is produced, by a stratigraphic inversion of seismic data with anamorphosis of impedances. Pre-injection and post-injection seismic data are acquired. A pre-injection seismic impedance cube IP1 is determined by a stratigraphic inversion of the pre-injection seismic data. An anamorphosis function ? is defined by a function comprising a positive lower limit B1, an upper limit B4, an identity interval defined between limits B2 and B3, with B1<B2<B3<B4. A value for each limit B1, B2, B3 and B4 is associated with each cell of the cube. Post-injection seismic impedances IP2 are determined by a stratigraphic inversion of the post-injection seismic data wherein the anamorphosis function ? is applied to seismic impedances IP2. The gas is located within the zone by identifying the cells where IP2<IP1.

Abstract: A system for automatically optimizing a Field Development Plan (FDP) for an oil or gas field uses a fast analytic reservoir simulator to dynamically model oil or gas production from the entire reservoir over time in an accurate and rapid manner. An objective function defining a Figure of Merit (FoM) for candidate FDPs is maximized, using an optimization algorithm, to determine an optimized FDP in light of physical, engineering, operational, legal and engineering constraints. The objective function for the Figure of Merit, e.g., net present value (NPV) or total production for a given period of time, relies on a production forecast from the fast analytic reservoir simulator for the entire FDP.

Abstract: A system, method and computer program product for generating scenarios of hydrocarbon reservoirs based on limited amount of information on a target hydrocarbon reservoir, and more particularly to automatically supplying missing parameters and uncertainty associated with each supplied parameter allowing to valuating the target hydrocarbon reservoir.

Abstract: A method for determining reservoir architecture using modeling of a non-equilibrium distribution of at least one analyte in reservoir fluids. The analyte(s) of the analysis preferably has (have) significant compositional variation in the reservoir. For example, the analyte can be a later charging single gas component (such as methane, carbon dioxide, or hydrogen sulfide) in a multi-component fluid system. In this case, the model can assume that the components of the early charge are in a stationary state or in equilibrium, whereas the later charge is in a state of non-equilibrium. The non-equilibrium distribution of the analyte(s) derived from the model is compared to the distribution of the analyte(s) derived from downhole or laboratory fluid analysis of reservoir fluid, and the architecture of the reservoir is determined based upon such comparison.

Abstract: A Markov decision process-based support tool for reservoir development planning can comprise a source of input data, an optimization model, a high fidelity model for simulating the reservoir, and one or more solution routines interfacing with the optimization model. The optimization model can consider unknown parameters having uncertainties directly within the optimization model. The model incorporates the flexibility that a decision-maker has in the real world and allows the decision-maker to adjust the decisions based on new information. The model can systematically address uncertain data, for example comprehensively or even taking all uncertain data into account. Accordingly, the optimization model can provide flexible or robust solutions that remain feasible over an uncertainty space. Once the reservoir model is optimized, final development plans may be generated.

Abstract: A processor accepts sensor data about a geological formation from a sensor. The sensor data is such that processing the sensor data using a processing technique to estimate a parameter of the geological formation without a constraint, whose value is not yet known, produces a plurality of non-unique estimates of the parameter. The processor accepts more than two time-displaced images of fluid sampled from the geological formation. The time displacements between the images are substantially defined by a mathematical series. The processor processes the images to determine the constraint. The processor processes the sensor data using the processing technique constrained by the constraint to estimate the parameter of the geological formation. The processor uses the estimated parameter to affect the drilling of a well through the geological formation.

Abstract: A method for controlling operations during construction of a subsurface wellbore includes measuring a plurality of wellbore construction parameters. At least one wellbore state parameter is calculated from the wellbore construction parameters in a computer. A plurality of users to communicate with the computer to enable access at least one of the measured wellbore construction parameters and the at least one wellbore state parameter. Depending on a assigned tasks, such user may receive task specific wellbore construction parameters and selected wellbore state parameters for display when a requested is communicated to the computer.

Abstract: Systems and methods for collecting, analyzing, transmitting, and acting on information collected from instruments monitoring and controlling equipment used for natural gas well production collection and pipeline insertion platforms (skids). Said instruments may include handheld computing devices like the Apple iPhone, iPad, or other PDAs; said devices using short or long range, wired or wireless communication. The systems and methods reduce costs, errors, inefficiencies, and increase safety by giving the user simple GUI interfaces for data collection and for action items. The said handheld devices can guide the data collector to the skid location using GPS or other location based services, collect data via wired of wireless methods, guide the data collector through manual data input methods or safety action items, compare current readings to past history and evaluate current safety or out-of-tolerance conditions or entries, among other items.

Abstract: The invention relates to a method for estimating a set of variables associated with sites of an area, the method comprising the following steps: a) a set of observation data is supplied, b) a variable associated with a site of a first sub-area is estimated by krigeing, using the precision matrix of the first sub-area, c) a second adjacent sub-area is determined, d) a variable associated with a site of the second sub-area is estimated by krigeing, on the basis of the first sub-space, the second sub-space, and the precision matrix determined for the first sub-space.

Abstract: Methods and systems are provided for rapidly estimating the hydrocarbon production potential of a subsurface hydrocarbon shale prospect or prospects. In short, the methods disclosed herein provide rapid mechanisms to determine sorbed gas storage of a shale reservoir with minimal delay and resource expenditure to aid operators in determining which prospects to exploit. In certain embodiments, an empirical implemented method for rapidly assessing hydrocarbon content of a shale reservoir comprises extracting one or more shale samples, performing a rock eval pyrolysis on the shale samples to determine certain geochemical properties of the shale, using the geochemical properties to determine a thermal maturity of the shale, determining a Langmuir volume of the shale, generating a adsorption isotherm of the shale, and determining a gas storage capacity of the shale. Advantages of the methods include a more efficient and rapid determination of shale gas storage with a minimal expenditure of resources.

Abstract: Multiple sensors in a wellbore can be utilized in a high density sweep analysis. In particular, annular pressures, recorded by the multiple sensors as the sweep is circulated, can be utilized to analyze the performance of a high density sweep. The high density sweep analysis can be used to create a prediction of the impact of circulating a high density sweep. The high density sweep analysis can calculate the position of the high density sweep in the well during the circulation by utilizing the multiple sensors and derive information about the presence of solids in the well, their likely location and whether or not the wellbore is clean prior to tripping out of the well.

Abstract: A method for evaluating portions of a reservoir includes classifying producing reservoir portions in the reservoir into multiple classifications based on production data associated with the producing reservoir portions. Each classification corresponds to a range of the production data. The method further includes generating a correlation between the classifications of the producing reservoir portions to a petrophysical property and elastic property of the subterranean formation, generating, based on the correlation, a spatial distribution function of reservoir quality to represent predicted classifications as a function of physical locations in the reservoir, and evaluating, using the spatial distribution function, a physical location in the reservoir for reservoir quality.