Class / Patent application number | Description | Number of patent applications / Date published |
702013000 | Hydrocarbon prospecting | 71 |
20080215245 | System and method for determining producibility of a formation using flexural mechanical resonator measurements - 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. | 09-04-2008 |
20080270033 | Methods of hydrocarbon detection using spectral energy analysis - 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. | 10-30-2008 |
20080288172 | Simulation method and apparatus for determining subsidence in a reservoir - 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, “ε | 11-20-2008 |
20080300793 | AUTOMATED FIELD DEVELOPMENT PLANNING OF WELL AND DRAINAGE LOCATIONS - 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. | 12-04-2008 |
20090005997 | Method for Spatial Filtering of Electromagnetic Survey Data - The method for suppressing noise in the controlled seismic source electromagnetic survey data based on the frequency content of the noise ( | 01-01-2009 |
20090043510 | Method for Quantifying Resistivity and Hydrocarbon Saturation in Thin Bed Formations - 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. | 02-12-2009 |
20090055098 | DETERMINATION OF POINT OF SAND PRODUCTION INITIATION IN WELLBORES USING RESIDUAL DEFORMATION CHARACTERISTICS AND REAL TIME MONITORING OF SAND PROTECTION - 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. | 02-26-2009 |
20090076730 | Data Adaptive Vibratory Source Acquisition Method - Method for conducting a seismic survey ( | 03-19-2009 |
20090143992 | METHODS AND APPARATUS TO DETERMINE A CONCENTRATION OF NITROGEN IN A DOWNHOLE FLUID - Methods and apparatus to determine a concentration of nitrogen in a downhole fluid are described. An example apparatus to determine a concentration of nitrogen in a downhole fluid includes a fluid measurement unit to measure a first fluid composition and a density of at least a hydrocarbon and carbon dioxide in a sample of the downhole fluid. Additionally, the example apparatus includes one or more sensors to measure at least a pressure and a temperature of the sample. Further, the example apparatus includes a processing unit to determine a first theoretical density based on at least the first fluid composition, the temperature, and the pressure the sample. Further still, the example apparatus includes an analyzer to determine a first difference between the density of at least the hydrocarbon and the carbon dioxide in the sample and the first theoretical density. The first difference is associated with a concentration of nitrogen in the sample. | 06-04-2009 |
20090248311 | DETERMINATION OF IRREDUCIBLE WATER CUT-OFF USING TWO DIMENSIONAL NUCLEAR MAGNETIC RESONANCE DATA - A method for estimating a distribution of pore sizes of a fluid filled rock formation penetrated by a borehole, the method including: processing nuclear magnetic resonance (NMR) data to determine a distribution of diffusion coefficients and a distribution of relaxation time constants for at least one depth in the borehole; plotting the distribution of diffusion coefficients and the distribution of relaxation time constants as a cross-plot for the at least one depth; identifying a water line on the cross-plot, each point on the water line having substantially the same value for the diffusion coefficient; and estimating the distribution of pore sizes from the distribution of relaxation time constants plotted along the water line. | 10-01-2009 |
20090292474 | Estimating gas-oil ratio from other physical properties - A method for characterizing a desired property of a fluid downhole is described. In some non-limiting examples, the method comprises receiving an input signal representing sound speed of a fluid downhole, processing the input signal using a correlation equation expressing the desired property in terms of at least sound speed to produce an output signal representing the desired property, and outputting the output signal. In some examples, the correlation equation is derived through a chemometric analysis of a training data set, the training data set comprises a plurality of input values and a plurality of output values derived from said input values, between the desired fluid property and the first measured property, and the output values are calculated from the input values using a series of correlation equations. In at least one example, the desired property is gas oil ratio. In another example, the desired property is gas brine ratio. In a further example, the series of correlation equations comprises the Batzle and Wang relations. In another example, the receiving comprises receiving a plurality of input signals representing a plurality of measured properties of a fluid downhole and the processing comprises processing the plurality of input signals using the correlation equation expressing the desired property in terms of the plurality of measured properties. | 11-26-2009 |
20090306899 | Geophysical surveying - Joint processing of seismic and controlled source electromagnetic (CSEM) surface data is performed by using a common rock physics model which relates reservoir properties (such as porosity, lithology, saturation, and shaliness) to surface seismic AVO (or AVA) data. This allows one to determine how perturbations in the reservoir properties affect surface data. This can be carried out by systematically changing the reservoir properties and examining the effect on the synthetic data. This allows the hydrocarbon type of a reservoir to be established, e.g. oil or gas, as well as the saturation level of the hydrocarbon in the reservoir, which is useful for determining whether the reservoir has a non-commercial, low hydrocarbon saturation or a commercial, high hydrocarbon saturation. | 12-10-2009 |
20090306900 | Rapid Inversion of Electromagnetic Reconnaisance Survey Data - Method for rapid inversion of data from a controlled-source electromagnetic survey of a subterranean region. Selected ( | 12-10-2009 |
20100169020 | METHOD AND APPARATUS FOR REAL TIME OIL BASED MUD CONTAMINATION MONITORING - The present invention is a method and apparatus for determining oil based mud contamination of a hydrocarbon fluid obtained from a wellbore during a formation testing. The invention includes receiving a model for simulating the contamination and receiving an empirical equation for computing the contamination. At a given pumping time, a simulated contamination is generated based on the model and an empirically computed contamination is generated based on the first empirical equation. The simulated contamination and empirically computed contamination are compared and a determination as to which is more reliable is made. Revision of the first model or first empirical equation based is then performed. | 07-01-2010 |
20100217531 | HYDROCARBON MEASUREMENT STATION PREVENTATIVE MAINTENANCE INTERVAL DETERMINATION - Hydrocarbon measurement station preventative maintenance interval determination. At least some of the illustrative embodiments are measurement stations configured to measure volumetric flow of hydrocarbons, where the measurement stations include a flow meter fluidly coupled to a piping system configured to carry at least one type of hydrocarbon flow, and a computer system comprising an interface device (the computer system electrically coupled to the flow meter and the computer system configured to maintain a plurality of parameters related to the volume of hydrocarbon flow in the piping). The computer system is configured to provide maintenance information for the measurement station, and the computer system provides the maintenance information at intervals determined based on constituents of hydrocarbons and based on parameters related to the volume of hydrocarbon flow in the piping. | 08-26-2010 |
20100228485 | METHOD FOR INTEGRATING RESERVOIR CHARGE MODELING AND DOWNHOLE FLUID ANALYSIS - A method for estimating properties of fluids in rock formations at selected locations within a geologic basin includes generating an initial model of the basin. The model includes as output spatial distribution of at least rock formation mineral composition, rock formation porosity and composition of fluids in the rock formation porosity. An initial estimate of fluid composition is generated for at least one rock formation at at least one selected location within the basin. A sample of fluid is extracted from pore spaces of the at least one rock formation from within a wellbore drilled therethrough. Composition of the fluid sample is analyzed from within the wellbore. The initial model of the basin is adjusted such that model predictions substantially match the analyzed fluid composition. The adjusted model is used to generate an initial estimate of fluid composition at at least one additional geodetic location within the basin. | 09-09-2010 |
20100268470 | System, Method, and Nanorobot to Explore Subterranean Geophysical Formations - An system and method for exploring geophysical formations at great depths below the surface of the earth. In order to explore the formation, nanorobots with a size less than 500 nanometers are inserted into the formation. The nanorobots propel through the formation, analyzing fluids and conditions as each moves through the formation. The nanorobots can communicate with a machine on the surface via a series of receivers and transmitters located in the wellbore. The machine on the surface is able to combine and analyze the data from the nanorobots to create a three dimensional map of the formation. The map shows the locations of pathways through the formation, pockets of hydrocarbons within the formation, and the boundaries of the formation. | 10-21-2010 |
20100274491 | METHOD AND APPARATUS FOR MONITORING OFFSHORE CONTAMINATION - 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. | 10-28-2010 |
20100305866 | ESTIMATING FLUID FLOW IN A RESERVOIR - The present disclosure relates to a method to improve the performance of reservoir simulators, and to widen the range of systems that can efficiently be modeled. The present disclosure relates to determining fluid flow in a subsurface reservoir. One embodiment divides the reservoir into discrete volume elements. Fluid within the volume elements is represented, for example, by it pressure, saturation, and/or composition. For one or more fluid phases comprising the fluid, the potential for each volume element is determined. The volume elements are ordered according to their potentials for each phase comprising the fluid. A local, fully coupled time-step sequence is determined using a local conservation solution based on the potential ordering of and for each fluid phase. The fluid flow is determined using a global conservation solution based on the local, fully coupled time-step sequence. | 12-02-2010 |
20110054797 | MAXIMUM ENTROPY APPLICATION METHODS AND SYSTEMS - Techniques for a maximum entropy approach to assigning probabilities, including those used in multiple realization history matching systems and methods, are disclosed. For example, in one embodiment, a method includes obtaining one or more available sample values Yi associated with a reservoir; computing a maximum entropy assignment λ of one or more discrete probabilities Pi(Yi) associated with each of the one or more available sample values Yi, where each discrete probability Pi(Yi) represents a probability that one or more variables Y will take a set of particular values Yi; and performing at least one determination regarding the reservoir using the maximum entropy assignment λ, including approximating a continuous probability distribution P(Y) using a sum of probability distributions Pi(Yi)+/−λ. | 03-03-2011 |
20110087435 | Method For Electromagnetic Prospecting Waveform Design - A waveform design method is presented for controlled source electromagnetic surveying. A desired source spectrum ( | 04-14-2011 |
20110144913 | SOURCE ROCK VOLUMETRIC ANALYSIS - An empirical method of measuring water saturation in hydrocarbon bearing formations is described. The system described herein accurately calculates water saturation, formation volume, total organic carbon, and other formation parameters under a variety of formation conditions. | 06-16-2011 |
20110264373 | Method For The Management of Oilfields Undergoing Solvent Injection - Solvent-dominated hydrocarbon recovery processes use chemical solvent(s), rather than a heat-transfer agent, as the principal means to achieve hydrocarbon viscosity reduction. Such processes are fundamentally different from thermally-dominated recovery processes and have unique challenges. Field measurements described herein, such as the rate of solvent production, can be used to manage solvent-dominated hydrocarbon recovery processes, for instance for improving hydrocarbon recovery or solvent efficiency. | 10-27-2011 |
20110282584 | SHALE ANALYSIS METHODS - 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. | 11-17-2011 |
20110313670 | METHOD AND APPARATUS FOR SPECIATING HYDROCARBONS - Described herein are a method and apparatus for analyzing a gas sample that is conveyed in a drilling fluid, and a method and apparatus for liberating gases from drilling fluid. The gas sample contains one or more of methane, ethane, propane, and butane; optionally, the gas sample may also contain pentane. The gas sample is first liberated from the drilling fluid, following which it is irradiated with infrared radiation in the near-infrared range. Absorption spectra resulting from absorption of the infrared radiation by the one or more of methane, ethane, propane and butane is simultaneously detected. From the absorption spectra, the composition of the gas sample can be determined. The composition includes a concentration of any one or more of the methane, ethane, propane and butane. Linearity of absorption is increased by using relatively short wavelength infrared radiation centred on, for example, about 1.70 μm, which can increase the accuracy of and reduce the computational intensity of the calculations utilized to determine the composition of the gas sample. Within the near-infrared range, radiation having a wavelength from about 1.55 μm to 1.85 μm can be used. Gases can be liberated from the drilling fluid using a gas trap. The gas trap can be powered using a brushless DC motor, and alternatively or additionally drilling fluid from a sample enclosure of the gas trap can exit via a bubbler enclosure of the gas trap. The brushless DC motor is a relatively efficiency and compact motor that can be used with the gas trap, and is advantageous over convention AC induction and air motor motors. Having drilling fluid exit the sample enclosure through the bubbler enclosure is advantageous in that it helps to make the footprint of the gas trap relatively small. | 12-22-2011 |
20110320128 | System and Method For Conformance Control In A Subterranean Reservoir - A system and method for optimizing the design of a conformance control treatment for a subterranean reservoir is disclosed. The system and method include performing tracer analysis between an injection well and a production well. A flow capacity and storage capacity curve is constructed from the tracer analysis. A storage capacity associated with a threshold residence time is determined using the flow capacity and storage capacity curve. A conformance control treatment is determined for the storage capacity associated with the threshold residence time. A chemical slug is injected into the injection well to increase the flow resistance in high permeability regions of a subterranean reservoir, thereby enhancing the recovery of hydrocarbons from the reservoir. | 12-29-2011 |
20120041681 | Water Fraction Measuring Sensor and Method - A sensor for measuring water fraction in a fluid mixture flowing in a conductive tubing within a borehole. The sensor comprises: an active probe, a reference probe, and an electronic unit. The active probe includes a first electrode and a second electrode isolated from each other by a first insulating layer, the first and second electrodes are preferably in contact with the fluid mixture. The reference probe is formed from an internal wall of the conductive tubing contacting the fluid mixture and isolated from the reference probe by a second insulating layer. The electronic unit is coupled to the first and second electrodes, and to the reference probe, the electronic unit preferably includes a capacitance module for measuring a capacitance between the active probe and the reference probe. | 02-16-2012 |
20120059591 | Systems and Methods for Collecting, Analyzing, Recording, and Transmitting Fluid Hydrocarbon Production Monitoring and Control Data - 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. | 03-08-2012 |
20120065890 | SYSTEM AND METHOD FOR HYDROCARBON GAS PAY ZONE CHARACTERIZATION IN A SUBTERRANEAN RESERVOIR - A system and computer-implemented method for characterizing hydrocarbon gas net pay zones in a subterranean reservoir including determining a sweet zone indicator from well log data, determining rock properties from well log data, and identifying one or more classes of net pay zones from the sweet zone indicator and rock properties. The sweet zone indicator may be determined by computing neutron-density separation and using the neutron-density separation and the well log data. The rock properties determined from the well log data may include total water saturation, adsorbed gas saturation, total gas content, porosity, propensity for hydraulic fracturing, uncertainty level of the total water saturation, uncertainty level of the total gas content, and baselines for the porosity and total gas content. Using the sweet zone indicator and rock properties, one or more classes of net pay zones can be identified. | 03-15-2012 |
20120150447 | METHOD FOR ANALYSING SEISMIC DATA WITH ATTRIBUTE FUNCTIONS - A method for stratigraphic analysis of seismic data, known as GeoLeaf, comprises: selecting a seismic data volume comprising a plurality of samples; selecting a number of horizons (TH, BH | 06-14-2012 |
20120158310 | METHOD OF DETERMINING RESERVOIR PRESSURE - A new approach is disclosed for measuring the pressure of tight gas reservoirs, using information obtain from continuous injection prior to hydraulic fracture stimulation. The technique can be obtained utilizing either bottom-hole or surface pressure gauges and properly instrumented surface injection pumps. The analysis is completed by plotting injection and rate data in a specialized form from terms arranged in Darcy's radial flow equation to obtain a curve or trend. The key component to proper application of this technique is to obtain both baseline and one or more calibration data sets. These calibration data sets are obtained by either increasing or decreasing the injection pressure and/or rate from the baseline data. Initial reservoir pressure is assumed, but the calibration data indicates if the guess was too high or low. Accurate estimates of reservoir pressure may be obtained in a few iterations. | 06-21-2012 |
20120253680 | Method and System for Passive Electroseismic Surveying - A method of passive surveying comprises generating one or more detected signals by passively detecting a signal generated within a subsurface earth formation due to a seismoelectric response or an electroseismic response in at least one porous subsurface earth formation containing at least one fluid, and processing the one or more detected signals to determine at least one property of the subsurface earth formation. | 10-04-2012 |
20120259552 | MONITORING THE PHASE COMPOSITION OF PRODUCTION FLUID FROM A HYDROCARBON EXTRACTION WELL - A method of monitoring a phase composition resulting from different phases in production fluid from at least one well of a plurality of hydrocarbon production wells is provided. The method comprises modulating a flow of production fluid from the at least one well; passing the flow of production fluid from each of the plurality of wells through a multiphase flow meter common to the plurality of wells; and processing data from the multiphase flow meter by responding to the modulation of the flow of the production fluid from the at least one well to produce information relating to the phase composition of the production fluid from the at least one well. | 10-11-2012 |
20120290211 | SYSTEM AND METHOD FOR DETERMINING PROPERTIES OF A HYDROCARBON RESERVOIR BASED ON PRODUCTION DATA - A system and computer-implemented method for determining properties of a hydrocarbon reservoir from production data is disclosed. The method includes obtaining production data for a plurality of wells in the hydrocarbon reservoir, arranging the production data for each of the wells such that the production data is indexed in three dimensions, displaying the arranged production data in a three dimensional graphical space to create displayed 3D production data, determining properties of the hydrocarbon reservoir based on the displayed 3D production data, and managing the hydrocarbon reservoir based on the properties of the hydrocarbon reservoir. | 11-15-2012 |
20120290212 | SYSTEM AND METHOD FOR HYDROCARBON PAY ZONE DEFINITION IN A SUBTERRANEAN RESERVOIR - The present invention is directed to methods and systems for defining hydrocarbon net pay zone using movable water volume estimates and hydrocarbon saturation uncertainty levels in lieu of fixed cut-offs to define the net pay zone. | 11-15-2012 |
20120316789 | METHOD FOR COST EFFECTIVE SAMPLING AND CHARACTERIZATION OF HETEROGENEOUS UNCONVENTIONAL HYDROCARBON REGIONS - A methodology improves sampling and characterization of heterogeneous, unconventional hydrocarbon-bearing regions. The methodology is designed to integrate consistently across measurements and scales. Additionally, the methodology involves characterizing various scales, such as regional-scale heterogeneity, wellbore-scale heterogeneity, core-scale heterogeneity, sample-scale, and pore-scale heterogeneity. The results are integrated across the multiple scales based on results obtained from the characterization of the scales. The methodology further comprises determining data propagation across the multiple scales in a hydrocarbon-bearing region. | 12-13-2012 |
20130066561 | Method and System for Passive Electroseismic Surveying - A method of passive surveying comprises generating one or more detected signals by passively detecting a signal generated within a subsurface earth formation due to a seismoelectric response or an electroseismic response in at least one porous subsurface earth formation containing at least one fluid, and processing the one or more detected signals to determine at least one property of the subsurface earth formation. | 03-14-2013 |
20130073210 | Method and System for Passive Electroseismic Surveying - A method of passive surveying comprises generating one or more detected signals by passively detecting a signal generated within a subsurface earth formation due to a seismoelectric response or an electroseismic response in at least one porous subsurface earth formation containing at least one fluid, and processing the one or more detected signals to determine at least one property of the subsurface earth formation. | 03-21-2013 |
20130173168 | Real-Time Dynamic Data Validation Apparatus and Computer Readable Media For Intelligent Fields - Apparatus and computer readable media for managing an intelligent field, are provided. An exemplary apparatus can include hydrocarbon well instruments, a SCADA system, a process integration server and/or dynamic field data analyzing computer, and memory/computer readable media storing a dynamic field data analyzing computer program. The computer program can include instructions that when executed cause the dynamic field data analyzing computer to perform various operations to include receiving real-time dynamic field data, analyzing validity of the dynamic field data, validating values of the field data, validating a state/condition of a well, and flagging well components, well conditions, and/or well state validation issues. | 07-04-2013 |
20130179083 | ESTIMATIONS OF NUCLEAR MAGNETIC RESONANCE MEASUREMENT DISTRIBUTIONS - A nuclear magnetic resonance (NMR) related distribution is estimated that is consistent with NMR measurements and uses linear functionals directly estimated from the measurement indications by integral transforms as constraints in a cost function. The cost function includes indications of the measurement data, Laplace transform elements and the constraints, and a distribution estimation is made by minimizing the cost function. The distribution estimation may be used to find parameters of the sample. Where the sample is a rock or a formation, the parameters may include parameters such as rock permeability and/or hydrocarbon viscosity, bound and free fluid volumes, among others. The parameters may be used in models, equations, or otherwise to act on the sample, such as in recovering hydrocarbons from the formation. | 07-11-2013 |
20130245953 | WELLBORE REAL-TIME MONITORING AND ANALYSIS OF FRACTURE CONTRIBUTION - Methods and apparatus are provided for calculating production of each of a plurality of fractured intervals (or fractures) and monitoring changes in the fracture contribution with time. Such real-time monitoring and analysis may be performed by combining temperature distribution (and pressure) measurements, a real-time surface multiphase flow measurement, and an inflow model for each fractured interval (or fracture). In this manner, the industry may be able to understand the behavior of fractures and, in turn, optimize the number of stages (i.e., fractured intervals), the number of fractures, and the spacing between fractures and stages. | 09-19-2013 |
20130282291 | MONITORING OF RESERVOIR FLUID MOVING ALONG FLOW PATHWAYS IN A PRODUCING OIL FIELD USING PASSIVE SEISMIC EMISSIONS - A system of and method for determining whether a liquid moving in an oil-bearing reservoir rock formation is water or oil is provided. The oil-bearing rock formation includes at production well(s) and source(s) of injected water during normal oil production. A fluid pathway is identified, baseline number of passive microseismic events is established, passive microseismic events in the fluid pathway are monitored during oil production to sense microseismic events, the sensed microseismic events are compared to a baseline number of passive microseismic events. The fluid causing the microseismic events is determined to be water if the sensed number of microseismic events approaches the baseline number of passive microseismic events per the predetermined unit, and if the baseline number of passive microseismic is measured during a time period when the water injection is greater than the rate of water injection during normal oil production. | 10-24-2013 |
20140052378 | METHODS AND CORRESPONDING SOFTWARE MODULE FOR QUANTIFYING RISKS OR LIKELIHOODS OF HYDROCARBONS BEING PRESENT IN A GEOLOGICAL BASIN OR REGION - Described herein are various embodiments of methods and corresponding hardware and software configured to quantify the risk or likelihood of hydrocarbons being present in a geological region. In such methods, first and second sets of regional or basin data corresponding to spatial and temporal variations in respective first and second petrophysical properties over at least portions of the region are generated, followed by generating a third set of regional data on the basis combining at least portions of the first and second sets of data. A visual display of the third set of data provides quantitative visual indications of degrees of risk or likelihood that hydrocarbons are present in the region at specified locations thereof. | 02-20-2014 |
20140088878 | ISOTHERM AND GAS-IN-PLACE ESTIMATION CONSIDERING CAPILLARY CONDENSATION IN SHALE GAS RESERVOIR - A method for estimating an amount of hydrocarbon in an earth formation having a kerogen includes determining a pore size in the kerogen at or below which capillary condensation will occur, the determining being performed using a processor. The method also includes calculating an amount of hydrocarbon liquid condensate in pores of the kerogen based on capillary condensation using the determined pore size, the calculating being performed using the processor. The method further includes estimating the amount of hydrocarbon in the earth formation using the calculated amount of hydrocarbon liquid condensate, the estimating being performed using the processor. | 03-27-2014 |
20140114577 | METHOD AND SYSTEM OF SELECTING HYDROCARBON WELLS FOR WELL TESTING - Selecting hydrocarbon wells for well testing. The selecting may include identifying hydrocarbon wells whose last well test took place prior to a predetermined date; dentifying hydrocarbon wells with a parameter that exceeds a predetermined threshold; and selecting a predetermined number of hydrocarbon wells from the wells identified. | 04-24-2014 |
20140121980 | PREDICTING THREE DIMENSIONAL DISTRIBUTION OF RESERVOIR PRODUCTION CAPACITY - 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. | 05-01-2014 |
20140149044 | COMPUTER ESTIMATION METHOD, AND METHOD FOR OIL EXPLORATION AND DEVELOPMENT USING SUCH A METHOD - 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. | 05-29-2014 |
20140156195 | Systems and Methods for Collecting, Analyzing, Recording, and Transmitting Fluid Hydrocarbon Production Monitoring and Control Data - 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. | 06-05-2014 |
20140172306 | INTEGRATED OILFIELD DECISION MAKING SYSTEM AND METHOD - 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. | 06-19-2014 |
20140200810 | Methods For Reservoir Evaluation Employing Non-Equilibrium Compositional Gradients - 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. | 07-17-2014 |
20140207383 | GENERATING HYDROCARBON RESERVOIR SCENARIOS FROM LIMITED TARGET HYDROCARBON RESERVOIR INFORMATION - 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. | 07-24-2014 |
20140257706 | Geological Model Analysis Incorporating Cross-Well Electromagnetic Measurements - 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. | 09-11-2014 |
20140278113 | Real-Time Determination of Formation Fluid Properties Using Density Analysis - 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. The probabilistic characterization of the state of the possible constituents allows, in turn, the probabilistic inference of formation properties such as contamination level and GOR. | 09-18-2014 |
20140297187 | JOINT INVERSION OF GEOPHYSICAL ATTRIBUTES - 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. | 10-02-2014 |
20140303895 | METHOD FOR DETERMINING THE LOCATION, SIZE, AND FLUID COMPOSITION OF A SUBSURFACE HYDROCARBON ACCUMULATION - 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. | 10-09-2014 |
20140343858 | MASS EXCHANGE MODEL FOR RELATIVE PERMEABILITY SIMULATION - 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. | 11-20-2014 |
20140379265 | REAL-TIME METHOD FOR DETERMINING THE POROSITY AND WATER SATURATION OF AN UNDERGROUND FORMATION USING GAS AND MUD LOGGING DATA - Real-time method for determining the porosity and water saturation of an underground formation using gas and mud logging data | 12-25-2014 |
20150032377 | SYSTEM AND METHOD FOR REMAINING RESOURCE MAPPING - 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 for a proposed infill well. | 01-29-2015 |
20150066373 | THREE-DIMENSIONAL RESERVOIR PRESSURE DETERMINATION USING REAL TIME PRESSURE DATA FROM DOWNHOLE GAUGES - 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. | 03-05-2015 |
20150094960 | QUALITY METRICS FOR TIGHT OIL RESERVOIRS - 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. | 04-02-2015 |
20150120196 | Method for Estimating Subsurface Properties from Geophysical Survey Data Using Physics-Based Inversion - 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 ( | 04-30-2015 |
20150293258 | SYSTEMS, MACHINES, METHODS, AND ASSOCIATED DATA PROCESSING TO EXPLORE AND ANALYZE SUBTERRANEAN GEOPHYSICAL FORMATIONS - Systems, methods, and transmitter assemblies for exploring geophysical formations at great depths. In order to explore the formation, transmitter assemblies with a size less than 500 nanometers are inserted into the formation. The transmitter assemblies propel through the formation, analyzing fluids and conditions as each moves through the formation. The transmitter assemblies can communicate with a machine on the surface via a series of receivers and transmitters located in the wellbore. The machine on the surface is able to combine and analyze the data from the nanorobots to create a three dimensional map of the formation. The map shows the locations of pathways through the formation, pockets of hydrocarbons within the formation, and the boundaries of the formation. | 10-15-2015 |
20150361792 | SYSTEMS AND METHODS FOR OPTIMIZING ANALYSIS OF SUBTERRANEAN WELL BORES AND FLUIDS USING NOBLE GASES - Systems and methods for monitoring and characterizing fluids in subterranean formations are provided. In one embodiment, a method for monitoring a well bore is provided, the method including: providing a first quantity of one or more noble gases of a known volume; circulating at least a portion of the fluid and the one or more noble gases in a portion of the well bore; detecting a second quantity of the noble gases in a portion of the fluid that has been circulated in a portion of the well bore; and determining one or more parameters relating to the well bore (e.g., well bore volume, lag time, flow characteristics, and/or efficiency of a gas extraction system) based on the quantities of the noble gases provided and/or detected in the fluid and/or the relative times at which the noble gases are provided or detected. | 12-17-2015 |
20160084080 | Method to Enhance Exploration, Development and Production of Hydrocarbons Using Multiply Substituted Isotopologue Geochemistry, Basin Modeling and Molecular Kinetics - A method and system are described that may be used for exploration, production and development of hydrocarbons. The method and system may include analyzing a sample for a geochemical signature, wherein the geochemical signature includes a multiply substituted isotopologue signature and/or a position specific isotope signature. Then, alteration timing may be determined from the signature(s) and used to develop or refine an exploration, development or production strategy. | 03-24-2016 |
20160123141 | RESERVOIR HYDROCARBON CALCULATIONS FROM SURFACE HYDROCARBON COMPOSITIONS - An apparatus for performing reservoir hydrocarbon calculations from surface hydrocarbon compositions during a drilling operation in a reservoir using a drilling fluid is described herein. The apparatus comprises a processor and a memory device coupled to the processor. The memory device may contains a set of instructions that when executed by the processor cause the processor to determine a raw gas value for a gas species measured at a surface gas analyzer; determine a first set of constant values corresponding to the gas species and the reservoir; determine a fluid characteristic of the drilling fluid; and calculate a subsurface gas concentration for the gas species based, at least in part, on the raw gas value, the first set of constant values and the fluid characteristic. | 05-05-2016 |
20160154129 | Determining Change In Permeability Caused By A Hydraulic Fracture In Reservoirs | 06-02-2016 |
20160177687 | FLOODING ANALYSIS TOOL AND METHOD THEREOF | 06-23-2016 |
20160177688 | FLOODING ANALYSIS TOOL AND METHOD THEREOF | 06-23-2016 |
20160177689 | FLOODING ANALYSIS TOOL AND METHOD THEREOF | 06-23-2016 |
20160177690 | FLOODING ANALYSIS TOOL AND METHOD THEREOF | 06-23-2016 |
20160201452 | MEASURING INTER-RESERVOIR CROSS FLOW RATE BETWEEN ADJACENT RESERVOIR LAYERS FROM TRANSIENT PRESSURE TESTS | 07-14-2016 |