Entries |
Document | Title | Date |
20080201080 | DETERMINING FLUID AND/OR RESERVOIR INFORMATION USING AN INSTRUMENTED COMPLETION - To determine fluid flow information associated with a well, data from plural discrete temperature sensors in zones without radial fluid flow in the well are received. The fluid flow information associated with the well is derived by combining the received data from the plural discrete temperature sensors with reservoir data that is independent of the fluid flow. That information can be further enhanced by monitoring the changes of temperature data over time. | 08-21-2008 |
20080234939 | Determining Fluid Rate and Phase Information for a Hydrocarbon Well Using Predictive Models - Physical models of wells are used to determine rate and phase composition for fluid produced from or injected into the wells on a near real time and continuous basis. The method can be used to alert operators or others of conditions in a well or field to permit more immediate response. The method can be more tolerant of sensor faults, sensor drift, anomalous data or other occurrences which could otherwise lead to incorrect output. More than one model can be used to permit a hierarchy of calculation such that the rate and phase determination is more tolerant of anomalous data. The calculated rate and phase values from one or more wells can be reconciled against facility data. | 09-25-2008 |
20080300792 | Method of measuring gas flow - A method of measuring a dry gas flow from hydrocarbon wells. The hydrocarbon wells produce a stream which contains liquids and natural gas. The method comprises providing an differential flow measurement device (orifice) located at a well site containing the hydrocarbon wells. The method further includes testing the stream for gas composition and physical characteristics. Additionally, the method comprises measuring a static temperature (T) of the stream, measuring a static pressure (Ps), and measuring a pressure differential (dP) in the differential flow measurement device (orifice). The method includes computing the liquid-gas ratio (LGR) of the stream, computing the wet gas flow rate (Qw) of the stream, computing a first dry gas flow rate (Qd | 12-04-2008 |
20090005996 | METHOD OF ESTIMATING THE PERMEABILITY OF A FRACTURE NETWORK FROM A CONNECTIVITY ANALYSIS - A method for optimizing the development of a fractured hydrocarbon reservoir wherein the network permeability is determined using a reliable compromise between numerical and analytical methods which has application to oil reservoir development. The reservoir is discretized into a set of grid cells and a geometrical description of the fracture network in each cell is elaborated. A connectivity index is then deduced within each cell for the fractures. The permeability of the fracture network of the cells whose connectivity index is above a first threshold is determined and a zero permeability value is assigned in the other cells. Other thresholds can be determined so as to choose between a numerical method and an analytical method to determine the permeability. These permeabilities are exploited in a flow simulator so as to optimize the development of the reservoir. | 01-01-2009 |
20090024327 | SYSTEM AND METHOD FOR MEASURING FLOW IN A PIPELINE - A system is provided for measuring flow in a pipeline which, in use, carries a stratified flow of a first liquid and a second, denser liquid. The system comprises: a section of the pipeline in which the stratified flow is uphill; a section of the pipeline in which the stratified flow is downhill; and a holdup meter on each of said pipeline sections for measuring the holdup in each section. The flow rates of the first and second liquids can be calculated from the measured holdups. | 01-22-2009 |
20090037113 | SUBSURFACE LAYER AND RESERVOIR PARAMETER MEASUREMENTS - Method and system for determining a characteristic of a subsurface formation traversed by a wellbore. A fluid flow rate in the wellbore is established, the flow being associated with fluid movement in one or more layers in the formation. Fluid data is generated from the fluid flow. The fluid flow rate in the wellbore is selectively altered, and fluid data is re-generated pertaining to the altered flow rates. The fluid data is processed to determine desired reservoir parameters and/or characteristics of an identified stratum in the formation. A method identifies inflexion points on a single phase oil only curve plot using the fluid data to determine layer characteristics and flow stability. | 02-05-2009 |
20090105957 | MEASUREMENT OF SOUND SPEED OF DOWNHOLE FLUID UTILIZING TUBE WAVES - A technique for utilizing tube waves to measure sound speed of fluids and other properties in the frequency range of about 5 to 100 kHz. A drill string is equipped with a sensor tube having a cavity filled with a downhole fluid such as borehole mud or formation fluid. An acoustic transmitter and an array of acoustic receivers are mounted on the tube in direct contact with the fluid. Processing circuitry calculates a property, e.g., sound speed, of the fluid based on time-of-flight of an acoustic signal generated by the transmitter and received by the array of receivers. Alternatively change in signal phase as a function of frequency may be employed by the processing circuitry. The technique is particularly suited to measuring the sound speed of borehole mud in situ. | 04-23-2009 |
20090143991 | MEASUREMENTS IN A FLUID-CONTAINING EARTH BOREHOLE HAVING A MUDCAKE - A method for determining true formation pressure in formations surrounding a fluid-containing borehole having a mudcake on the surface thereof, including the following steps: at a particular location in the borehole, monitoring the electrokinetic potential across the mudcake; modifying the borehole pressure at the particular location in the borehole; and determining the true formation pressure in the formations surrounding the particular location as being the borehole pressure at which the electrokinetic potential is substantially zero. | 06-04-2009 |
20090204328 | REFINED ANALYTICAL MODEL FOR FORMATION PARAMETER CALCULATION - Disclosed herein are methods, systems, and devices for determining parameters of an earth formation. Pressure transient data from a formation test can be recorded and analyzed using an analytical model including one or more correction factors derived from an assumption that an induced flow within the formation is hemispherical. Regression analysis of the refined analytical model and the pressure transient data results in accurate earth formation parameters. | 08-13-2009 |
20090204329 | SIMULTANEOUS ANALYSIS OF TWO DATA SETS FROM A FORMATION TEST - Disclosed herein are methods, systems, and devices for determining parameters of an earth formation. Pressure transient data from a formation test can be recorded and analyzed using an analytical model including one or more correction factors derived from an assumption that an induced flow within the formation is hemispherical. Regression analysis of the refined analytical model and the pressure transient data results in accurate earth formation parameters. | 08-13-2009 |
20090299637 | Continuous Reservoir Monitoring for Fluid Pathways Using Microseismic Data - A system and method monitor a hydrocarbon reservoir for drainage in volumetric three dimensions. Monitoring between wells is imperative for optimum reservoir management and is achieved by mapping the hydrocarbon fluid pathways in a producing reservoir. Unlike conventional 4D or time-lapse reflection seismic imaging systems that use a controlled active seismic source and records reflected seismic energy at receivers, the system and method exploit the minute vibrations, or micro-earthquakes generated in the reservoir layers that are induced by fluid movement. These microseisms are detected as the fluids move in the reservoir. | 12-03-2009 |
20090326827 | PHASE BEHAVOIR ANALYSIS USING A MICROFLUIDIC PLATFORM - Methods and related systems are described for analyzing phase properties in a microfluidic device. A fluid is introduced under pressure into microchannel, and phase states of the fluid are optically detected at a number of locations along the microchannel. Gas and liquid phases of the fluid are distinguished based on a plurality of digital images of the fluid in the microchannel. Bi-level images can be generated based on the digital images, and the fraction of liquid or gas in the fluid can be estimated versus pressure based on the bi-level images. Properties such as bubble point values and/or a phase volume distribution ratio versus pressure for the fluid are can be estimated based on the detected phase states of the fluid. | 12-31-2009 |
20100023269 | MANAGING FLOW TESTING AND THE RESULTS THEREOF FOR HYDROCARBON WELLS - Automated monitoring and management of well tests of hydrocarbon wells in a production field. Routing of the output of a well to a flow meter, separated from the output from other wells in the field, is detected by a computer system such as a server. Measurement data including the flow as measured by the flow meter, and also other measurements such as temperatures and pressures contemporaneous with the flow meter measurements, are acquired by the computer system; a stable period is identified, over which the flow test measurement data are considered valid. Upon completion of a specified duration or upon a change in the flow environment, the computer system notifies the user of the completion of the flow test. The flow test results can be used to modify predictive well models, with the modification dependent on validation by the user. The system can also plan and schedule future flow tests. | 01-28-2010 |
20100070182 | METHOD IN AN OIL AND/OR A GAS PRODUCTION SYSTEM - A method in an oil and/or a gas production system including a plurality of oil and/or gas wells and parameter testers adapted for oil and/or gas production parameter testing. The method is adapted to compare a plurality of options related to the oil and/or gas throughput in the oil and/or gas production system. A plurality of parameter samples are drawn from a parameter distribution. A performance measure is generated for each parameter sample by using the parameter sample and a characterizer for each of the options. An aggregated performance measure is generated for each of the options by using the performance measures. | 03-18-2010 |
20100082258 | SYSTEM AND METHOD FOR MODELING FLUID FLOW PROFILES IN A WELLBORE - A system for measuring a fluid flow rate in a wellbore disposed in an earth formation is disclosed. The system includes: a wellbore assembly configured to be disposed along a length of a wellbore, the wellbore configured to receive a wellbore fluid therein; a distributed temperature sensor (DTS) assembly disposed along the length of the wellbore and configured to take a plurality of temperature measurements along the length of the wellbore; and a processor in operable communication with the fiber optic sensor, the processor configured to receive the temperature measurements and apply a fluid flow rate model of fluid flow rates to the temperature measurements to calculate a fluid flow profile of the wellbore. The model is based on a steady-state energy balance between the wellbore fluid and the earth formation and a Joule-Thomson coefficient including a liquid volume expansion factor and a fraction of gas in the wellbore fluid. | 04-01-2010 |
20100082259 | PERCOLATION TEST APPARATUS - The present invention includes a method and apparatus for determining the percolation rate of soil. The method includes providing a test assembly configured to be placed over the top of a test hole, the test assembly containing a remote sensor (such as an ultrasound sensor) positioned proximate the top of the hole. The depth to the bottom of the hole, as well as the elevation of water within the hole during the test process, is measured using the remote sensor and used to determine perc rate of the soil within which the hole is dug | 04-01-2010 |
20100169019 | FORMATION EVALUATION USING LOCAL DYNAMIC UNDER-BALANCE IN PERFORATING - Methods for estimating an unknown value for a dynamic under-balance condition are herein disclosed. The unknown value may be a well property value, or may be a transient pressure characteristic. Embodiments of the method include selecting at least one transient pressure characteristic and selecting at least one well property value. A correlation between the at least one transient pressure characteristic and at least one well property value is obtained. The unknown value is estimated by applying at least one known transient pressure characteristic or at least one known well property value to the obtained correlation. | 07-01-2010 |
20100250142 | SYSTEM AND METHOD OF ANALYZING FLUIDS AT A DRILLING LOCATION - A system for monitoring fluids at a drilling location, the system including a viscometer ( | 09-30-2010 |
20100268469 | MICROFLUIDIC OSCILLATING TUBE DENSITOMETER FOR DOWNHOLE APPLICATIONS - Devices, methods and systems for determining one or more properties of at least one fluid sample. A tube configured to receive the at least one fluid sample wherein the tube is placed in a pressure housing. Further, an excitation source configured to generate vibration of the tube whereby a circulation of an electrical current along a portion of the tube is subjected to at least one magnetic field produced by at least one magnet. Further still, at least one vibration sensor that converts vibrations of the tube into a measurement signal. Finally, a processor that receives the measurement signal determines a resonant frequency from the measurement signal using a frequency measuring device to determine a property of the one or more properties of the at least one sample fluid. | 10-21-2010 |
20100274490 | THICKNESS-INDEPENDENT COMPUTATION OF HORIZONTAL AND VERTICAL PERMEABILITY - A method for determining permeability of a reservoir using a packer-probe formation testing tool. The elements of the method include generating, using a dual packer tool module, fluid flows from the reservoir into a wellbore, obtaining pressure data associated with the fluid flows using an observation probe tool module, wherein the packer-probe formation testing tool comprises the dual packer module and the observation probe tool module, identifying a portion of the pressure data corresponding to a spherical flow regime, determining horizontal permeability based on the portion of the pressure data, and displaying an output generated using the horizontal permeability. | 10-28-2010 |
20100280757 | Multi-Phase Fluid Measurement Apparatus and Method - The present disclosure provides a flowmeter including a vibrating element configured to be inserted in a measured fluid; a driver circuit to vibrate the vibrating element in its natural frequency of oscillation; one or more additional technology flow meters configured to measure an additional property of the fluid; a data acquisition circuit configured to measure signals effected by the flow of a multi-phase fluid; and a computer suitable to solve non-linear simultaneous equations. The fluid may include gas, oil and/or water. The fluid may also include solids. | 11-04-2010 |
20100286917 | METHOD AND SYSTEM FOR REPRESENTING WELLS IN MODELING A PHYSICAL FLUID RESERVOIR - The disclosure is directed to a method of representing fluid flow response to imposed conditions in a physical fluid reservoir through wells. The invention utilizes techniques and formulas of unprecedented accuracy and speed for computations for a fundamental element in analysis of fluid movement through subterranean reservoirs—the calculation of Green's and Neumann functions in finite three-dimensional space. The method includes modeling of pressure and/or flow rate observables at wells in said reservoir using an easily computable, closed-form Green's or Neumann function for a linear well segment in arbitrary orientation within a three dimensional cell of spatially invariant but anisotropic permeability. The method further includes the modeling of fluid flow in the physical fluid reservoir with an assemblage of linear well segments operating in unison with uniform flux density to represent arbitrary well trajectory. The method further includes modeling reservoir flow through one or more linear well segments of non-uniform flux related by a constitutive expression linking pressure distribution and flow rate within the well. The method further includes generalization through integration of easily computable Green's or Neumann functions to represent fractures or fractured wells in modeling fluid flow in a physical reservoir. The system includes modeling fluid flow through a mesh representation of the physical fluid reservoir containing one or more wells represented by easily computable Green's or Neumann functions. The system further includes modeling of flow in the physical reservoir via a numerical method in which the values of pressure and flux assigned to the mesh are related to observables at the well using aforementioned easily computable Green's or Neumann functions. The system further includes the coupling of well and mesh values within the numerical solution method for well observation or feedback control. The system still further includes the localization of the well model to the properties assigned to only those mesh elements penetrated by the well using boundary integral equation methods. The invention also incorporates the addition of transients in fluid flow towards a steady or pseudo-steady state, and use thereof, in the above constructs. | 11-11-2010 |
20100286918 | APPARATUS AND METHOD FOR PREDICTING PROPERTIES OF EARTH FORMATIONS - A method of predicting a property of an earth formation includes: injecting a fluid into at least one pre-existing feature of the formation at a plurality of constant pressures or flow rates; measuring a response from the at least one pre-existing feature at each of the plurality of constant pressures or flow rates; and estimating at least one property of the at least one pre-existing feature based on the response. An apparatus for predicting a property of an earth formation is also disclosed. | 11-11-2010 |
20100312480 | METHOD FOR MONITORING FLUID FLOW IN A MULTI-LAYERED SYSTEM - A method for monitoring the movement of fluid through a subsurface formation of interest, comprising: a) providing a set of signals obtained by transmitting seismic waves through the formation of interest and receiving signals emanating from the multi-layered system in response to the seismic waves with one or more receivers located a distance from the seismic source(s), b) identifying one or more critically refracted waves among the signals so as to generate a first data set of refracted signals, c) repeating steps a) and b) after a period of time so as to generate a second data set of refracted signals, d) comparing the second data set to the first data set so as to generate a time-lapse data set, e) imaging the time-lapse data set using travel time tomography; and f) inferring information about the movement of fluid based on the image generated in step e). | 12-09-2010 |
20110022320 | METHOD OF PREDICTING MECHANICAL PROPERTIES OF ROCKS USING MINERAL COMPOSITIONS PROVIDED BY IN-SITU LOGGING TOOLS - A method for predicting mechanical properties of a transverse isotropic region of a rock formation traversed by a well bore including running a logging tool in the well bore; the mass percentages of minerals present in the rock formation surrounding the well bore are measured with the logging tool. The density of the minerals present in the rock formation surrounding the well bore is determined. The porosity of the rock formation surrounding the well bore is measured. From the porosity and the measured mass percentages and density of the minerals, all the transverse isotropic elastic coefficients of the rock formation are determined in real time. | 01-27-2011 |
20110040485 | METHOD OF MEASURING MULTI-PHASE FLUID FLOW DOWNHOLE - Multi-phase flow is estimated in a flow meter by measuring fluid pressure within the flow meter and using the measured pressure to calculate a density of the flow. A total flow rate through the flow meter is estimated based on the calculated density and a PVT analysis of the fluid. A corrected total mass flow rate is calculated using a liquid/gas slip correction technique. Fluid flow rates are further corrected with a discharge coefficient that varies with changes in the Reynolds number of the fluid. The gas and oil fractions can be determined from the corrected total mass flow rate and gas fraction. | 02-17-2011 |
20110054796 | METHOD FOR CALCULATING THE RATIO OF RELATIVE PERMEABILITIES OF FORMATION FLUIDS AND WETTABILITY OF A FORMATION DOWNHOLE, AND A FORMATION TESTING TOOL TO IMPLEMENT THE SAME - A method and a tool that implements a method which includes measuring the viscosity and flow rates of formation fluids and obtaining the ratio of relative permeabilities of the formation fluids and wettability of the formation using the same. | 03-03-2011 |
20110098931 | System and method for obtaining and analyzing well data - A system and method including a sensors deployed in a wellbore, the sensors measuring various downhole parameters. The system retrieves the relevant data from the sensors, validates the data, conditions the data, and analyzes the data to diagnose the wellbore and the reservoir to indicate trends therein. The system has the capability of enabling the characterization of the wellbore and reservoir by being linked to well test analysis tools. The system also has a screening analysis that is much less time consuming than well test analysis tools and that indicates to a user which wellbore and/or reservoirs should be subjected to the more robust and time consuming well test analysis tool. | 04-28-2011 |
20110130966 | METHOD FOR WELL TESTING - The present document discloses techniques to perform an impulse well test for formation property estimation of subsurface reservoirs. It disclosures a method to obtain the optimum time range of a downhole isolation valve closure to achieve an acceptable depth of investigation for an impulse test and methodologies to optimize the execution of an impulse test using the simulated and measured real time bottomhole pressure data. It is emphasized that this abstract is provided to comply with the rules requiring an abstract which will allow a searcher or other reader to quickly ascertain the subject matter of the technical disclosure. It is submitted with the understanding that it will not be used to interpret or limit the scope or meaning of the claims. | 06-02-2011 |
20110178713 | CABLE INSTALLATION APPARATUS - A device for detecting a flow of air from an exit end of a tube fed into an entrance end of the tube, including a bore having a first section with a first size bore size and a second section with a second bore size, an obstruction located within the bore between the first section and the second section, the obstruction configured to obstruct air flowing from the first section to the second section, and fixing means to fix the device to the tube so that the bore communicates with the exit end of the tube, wherein in use, an air pressure sensor is used to compare air pressure within the first bore section and air pressure within the second bore section, so that a pressure differential is indicative of an air flow within the bore. | 07-21-2011 |
20110218736 | FORMATION FLUID PROPERTY DETERMINATION - In some embodiments, an apparatus and a system, as well as a method and an article, may operate to obtain a formation fluid sample from a formation adjacent to a wellbore disposed in a reservoir, determine the sample saturation pressure of the formation fluid sample, repeat obtaining the formation fluid sample and determining the sample saturation pressure over a selected time period or number of samples, and determine a predicted ultimate formation fluid saturation pressure based on multiple determinations of the sample saturation pressure. The sample saturation pressures measured over selected time periods can be used to determine fluid sample contamination. Additional apparatus, systems, and methods are disclosed. | 09-08-2011 |
20110231099 | PORTABLE GAS MONITOR - A portable monitor used to measure landfill gas and landfill well parameters. The portable monitor includes a control unit and a measuring unit that can communicate wirelessly with one another. The control unit and/or measuring unit can include a heating arrangement to increase the temperature of one or more components in the control unit and/or measuring unit in cold environments. | 09-22-2011 |
20110257887 | UTILIZATION OF TRACERS IN HYDROCARBON WELLS - Monitoring of a wellbore which penetrates a reservoir is carried out by providing tracer material at one or more subterranean locations within or proximate the wellbore, so that tracer may enter the flow and be present in flow from the wellbore; repeatedly taking samples from the flow from the wellbore, and analyzing the samples for the presence of tracer, in the vicinity of the wellsite. Taking samples from the flow will generally be done at the surface and may be done by automatic equipment controlled by a programmed computer. The computer may be programmed to take action, such as operating a valve within the well, in response to detection of tracer. Sampling repeatedly and analyzing on site can provide information in something close to real time and thus integrates the use of tracers into an overall process of monitoring and control. | 10-20-2011 |
20110288778 | METHOD FOR ESTIMATION OF SAGD PROCESS CHARACTERISTICS - The invention relates to thermally stimulated oil recovery in horizontal wells, namely to the methods for estimation of Steam Assisted Gravity Drainage (SAGD) process characteristics. Method for estimation of SAGD process characteristics is characterized by the steps of measuring temperature along the injection well, measuring steam quality and injection rate at the inlet of the injection well, estimating the pressure distribution profile by using the data obtained, estimating steam injection profile by using the obtained pressure profile and injection rate combined with ID injection well model for pressure losses in the wellbore and heat exchange between injection well tubing and annulus. The obtained steam injection profile is used as an input parameter for a set of 2D cross-sectional analytical SAGD models taking into account reservoir and overburden formation properties impact on production parameters and SAGD characteristics. SAGD process characteristics are estimated on the basis of energy conservation law for condensed steam taking into account heat losses into the reservoir and overburden formation and hence the fluid production rate changing in time. | 11-24-2011 |
20110295509 | WELLBORE FLUID TESTING APPARATUS AND METHODS - A system for testing a wellbore fluid includes a test chamber having first and second platens therein. The chamber is in a thermally insulating enclosure. The enclosure includes a heating element. The platens simulate response of the wellbore fluid through an hydraulically induced fracture in subsurface rock formation. The system includes means to control a distance between the platens. A pump introduces the wellbore fluid into a space between the platens and another pump introduces a pressure test fluid into contact with the wellbore fluid. A respectve pressure sensor is in fluid communication with a discharge side of each pump, and a sensor is included to measure a parameter related to the position of the second platen or the space between the platens. A data acquisition and control device is configured to detect signals from the respective pressure transducers and the sensor. | 12-01-2011 |
20110301851 | METHOD FOR VIRTUAL METERING OF INJECTION WELLS AND ALLOCATION AND CONTROL OF MULTI-ZONAL INJECTION WELLS - A method for virtual metering of fluid flow rates in a cluster of fluid injection wells which are connected to a collective fluid supply header conduit assembly comprises: a) sequentially testing each of the injection wells of the cluster by closing in that well and then performing a dynamically disturbed injection well test (DDIT) on the tested well, during which test the injection rate to the tested well is varied over a range of flows whilst the fluid flowrate in the header conduit assembly and one or more injection well variables, including tubing head pressure, of the well under test and of the other wells in the cluster are monitored, and the other wells in the cluster are controlled such as to cause their tubing head pressures or flow meter readings to be approximately constant for the duration of the test; b) deriving from step a a well injection estimation model for each tested well, which model provides a correlation between variations of the fluid flowrate attributable to the well under consideration in the header conduit assembly, and variations of one or more well variables monitored during each dynamically disturbed injection well test (DDIT); c) injecting fluid through the header conduit assembly into the cluster of wells whilst a dynamic fluid flow pattern in the header conduit assembly and one or more well variables of each injection well are monitored; d) calculating an estimated injection rate at each well on the basis of dynamic fluid flow pattern in the header conduit and the monitored well variables and the well injection estimation model of step b. | 12-08-2011 |
20110320127 | METHODS AND APPARATUS TO CONTROL A FORMATION TESTING OPERATION BASED ON A MUDCAKE LEAKAGE - Methods and apparatus to control a formation testing operation based on a mudcake leakage are disclosed. A disclosed example method for use with a downhole tool disposed in a wellbore comprises measuring a property of a mudcake layer at a first location in a wellbore, determining a value representative of an estimated leakage through the mudcake layer based on the property, and determining, based on the value, whether to continue a formation testing operation. | 12-29-2011 |
20120041680 | Resonance Method of Finding Permeability of Rocks From Parameters of Radial Waves - Radial waves are generated in a borehole in a saturated porous earth formation. Measurements are made of the velocity of motion of the formation and the fluid in the formation. The difference in the velocities is indicative of formation permeability. | 02-16-2012 |
20120046870 | MULTIPHASE FLOW METER FOR SUBSEA APPLICATIONS USING HYDRATE INHIBITOR MEASUREMENT - Methods and apparatus for determining phase fractions (relative concentrations) within a multiphase fluid mixture, in the presence of an injected hydrate inhibitor. Combining this phase fraction information with a hydrate inhibitor injection rate (HIIR) enables resolving oil and water flow rates for the phase fractions. The liquid flow rates and a total combined flow rate of the fluid mixture—determined based on a differential pressure of the fluid mixture through a given area—enable resolving a gas flow rate. | 02-23-2012 |
20120095688 | Radial Waves In A Borehole And Stoneley Waves For Measuring Formation Permeability And Electroacoustic Constant - A Stoneley wave is generated in a borehole in a saturated porous earth formation. Measurements are made of the velocity of motion of the formation and the fluid in the formation. The difference in the velocities is indicative of formation permeability. An additional measurement of the electric field at the borehole wall enables determination of the electroacoustic constant. | 04-19-2012 |
20120116681 | DETECTING AND LOCATING FLUID FLOW IN SUBTERRANEAN ROCK FORMATIONS - A method and system includes acquiring a seismic dataset while fluids are injected into the subsurface with seismic data recorded at multiple sensor locations. Seismic travel times are computed between sensors and subsurface locations using a velocity model. Travel times and travel time delays between pairs of sensors may be used as input to determine a similarity coefficient associated with subsurface positions. The similarity coefficients are determined using cross correlation, semblance calculations or eigenstructure decomposition. The coefficient values are related to the acoustic response at each subsurface position and may be summed together for each position for comparison with other subsurface positions to determine the position of a fluid front moving through the subsurface. The values may be displayed to illustrate the position of fluids in the subsurface and displayed to show the time variance of the fluid position. | 05-10-2012 |
20120136578 | RISE IN CORE WETTABILITY CHARACTERIZATION METHOD - The various embodiments herein provide a method for determining core wettability characteristics of reservoir rock samples based on modified form of Washburn equation. The method involves saturating a core sample with a first reservoir fluid such as water and imbibing with a second reservoir fluid such as oil. The change in square of the core mass with respect to time is monitored during an imbibition process to acquire a data to calculate a contact angle to determine the wettability of the sample. The contact angle is calculated by using the modified form of Washburn equation. A single or twin core sample is used to calculate the wettability characteristics. The method measures wettability characteristics in terms of contact angle and not in terms of wettability index. | 05-31-2012 |
20120136579 | Apparatus and Method for Detecting and Quantifying Leakage in a Pipe - The present invention is directed toward a method and an apparatus to investigate and quantify a leakage rate for a fluid (FG, FL) between a first pipe and a second pipe, the first pipe being surrounded by at least a portion of the second pipe, where the pipes are arranged in a well in a ground and where a measuring arrangement including a flow meter and a pressure meter is put into fluid communication with an annulus (B) defined by the first pipe and the second pipe, where fluid (FG) in the gaseous phase is conveyed through the measuring arrangement, as the annulus (B) is used as a separation chamber for gas (FG) and liquid (FL). | 05-31-2012 |
20120158308 | Canted Helix Collapsible Flowmeter and Method of Measuring A Fluid Flow - Flowmeters and methods of measuring a fluid flow or manufacturing flowmeters are presented. A flowmeter has a tool body and one or more spinner arms configured to extend with a first end away from the tool body and a second end joined to the tool body, when deployed to measure a fluid flow. Each spinner arm includes a helical blade configured to rotate due to a fluid flowing substantially parallel to a longitudinal axis of the tool body, around a rotation axis between the first end and the second end. | 06-21-2012 |
20120158309 | Modeling Immiscible Two Phase Flow in a Subterranean Formation - The propagation of a flood front as it is being injected in a porous media segment such as a subterranean oil-bearing formation or a core composite is measured as a function of time during a number of discrete time steps. A model is formed of measures of water saturation profiles along the length of travel through the porous media segment for the time steps. The model in effect subdivides the porous media segment into individual sections or subsystems of equal distances. The saturation of each subsystem is determined based on the volume of the fluid injected, the pre-determined fractional flow and the initial average saturation. | 06-21-2012 |
20120166089 | Job Monitoring Methods and Apparatus for Logging-While-Drilling Equipment - Job monitoring methods and apparatus for logging-while-drilling equipment are disclosed. A disclosed example method includes obtaining a fluid associated with an underground geological formation, analyzing the fluid with one or more sensors to form respective ones of sensor outputs, identifying a downhole scenario associated with the fluid based on the sensor outputs, the identifying being performed while the sensors are within the underground geological formation, and selecting a telemetry frame type based on the identified downhole scenario. | 06-28-2012 |
20120203463 | Fluid Rheology Measurement Using a Funnel Apparatus - Methods for determining fluid rheology, the methods including determining a first discharged volume or weight of a fluid at a first time, determining at least a second discharged volume or weight of the fluid at a second time, and calculating fluid rheology based on the determined first and at least second discharged fluid volumes or weights at the first and second times. | 08-09-2012 |
20120209529 | Determining Fluid Rate And Phase Information For A Hydrocarbon Well Using Predictive Models - Physical models of wells are used to determine rate and phase composition for fluid produced from or injected into the wells on a near real time and continuous basis. The method can be used to alert operators or others of conditions in a well or field to permit more immediate response. The method can be more tolerant of sensor faults, sensor drift, anomalous data or other occurrences which could otherwise lead to incorrect output. More than one model can be used to permit a hierarchy of calculation such that the rate and phase determination is more tolerant of anomalous data. The calculated rate and phase values from one or more wells can be reconciled against facility data. | 08-16-2012 |
20120215452 | SYSTEM AND METHOD FOR WATERFLOOD MANAGEMENT - A method of producing hydrocarbons in a reservoir includes determining a relationship between an injection well and a producing well based on an injection rate and a production rate wherein the relationship is filtered to produce a filtered value, and a modified state variable model is selected for each relationship to produce a positive relationship value to determine the production rate. | 08-23-2012 |
20120277997 | DEVICE AND A SYSTEM AND A METHOD OF EXAMINING A TUBULAR CHANNEL - The invention relates to a device for examining a tubular channel, the device comprising a three-way valve, buoyancy means, pressure means, a vent line, at least one sensor and computation means; wherein the three-way valve controls the fluid flow between the pressure means and the buoyancy means and between the buoyancy means and the vent line; the computation means is communicatively coupled to the at least one sensor and adapted to generate a control signal based on data received from the at least one sensor; and wherein the pressure means is fluidly coupled to the buoyancy means via the three-way valve such that a fluid may flow from the pressure means to the buoyancy means or from the buoyancy means to the surroundings of the device via the vent line; and wherein the computation means is communicatively coupled to the three-way valve and controls said three-way valve via the control signal. Thereby, the invention is able to examine e.g. oil wells containing obstructions such as wash-outs and/or side tracks and/or non-linear parts in open hole completions of the well. | 11-01-2012 |
20120303281 | ENHANCED DYNAMIC WELL MODEL FOR RESERVOIR PRESSURE DETERMINATION - A computer implemented method for determining reservoir pressure in a shut-in well, the method comprising: determining the initial physical characteristics of the well; determining properties of gas bubble throughout the well; calculating a dynamic mass transfer rate for the gas bubble over a period of time; calculating the physical fluid movement along the well: calculating a rate of fluid influx from the reservoir; determining a corrected pressure gradient along at least part, or all, of the profile of the well using the determined dynamic mass transfer rate, fluid movement and rate of fluid influx; and determining the reservoir pressure from a measure, or determination, of the well head pressure and the calculated pressure. | 11-29-2012 |
20120316788 | Formation Testing Planning And Monitoring - An example method comprises collecting formation temperature data along a wellbore extending into a subterranean formation, determining test operating parameter values, performing a wellbore hydraulic simulation of the response of wellbore fluid conditions to the test operating parameter values and the formation temperature data, determining whether the response of wellbore fluid conditions is indicative of one of a well control and a well stability problem, and initiating a test based on the determination whether the response of wellbore fluid conditions is indicative of one of a well control and a well stability problem. | 12-13-2012 |
20130041588 | FLOW MANAGEMENT SYSTEM AND METHOD - A monitoring tool is provided for monitoring wells for flow anomalies. The temperatures of flowing well fluid and ambient temperature are monitored and various methods applied to indicate if a well is normal flowing, at risk of flow stoppage or cessation of flow. Approaches are described for determining trending indicators from actual flow temperatures compared to a normal flow relationship for establishing the presence of flow anomalies. Temperature sensors, onsite processors and communications upload data for display of well status flags on a mapping module enabling pro-active detection and preventative action by operators. | 02-14-2013 |
20130096835 | Clustering Process for Analyzing Pressure Gradient Data - Clustering analysis is used to partition data into similarity groups based on mathematical relationships between the measured variables. These relationships (or prototypes) are derived from the specific correlation required between the measured variables (data) and an environmental property of interest. The data points are partitioned into the prototype-driven groups (i.e., clusters) based on error minimization. Once the data is grouped, quantitative predictions and sensitivity analysis of the property of interest can be derived based on the computed prototypes. Additionally, the process inherently minimizes prediction errors due to the rigorous error minimization during data clustering while avoiding overfitting via algorithm parameterization. The application used to demonstrate the power of the method is pressure gradient analysis. | 04-18-2013 |
20130103319 | METHODS FOR DETERMINING WELL CHARACTERISTICS AND PORE ARCHITECTURE UTILIZING CONVENTIONAL WELL LOGS - Methods, computer readable medium, apparatus, and program code for determining well characteristics and pore architecture for a hydrocarbon well utilizing data available from conventional/standard electronic well logs, are provided. An example of a method can include determining the value of well constants from well log data to include calculating water saturation, free water level location, wettability, and pore throat heterogeneity, and calculating pore architecture at log resolution responsive thereto. This can be accomplished, for example, by accessing well log data from a conventional well log, determining a linear regression line responsive to parameters calculated from the well log data, the linear regression line having a slope and an intercept, and determining a value of each of a plurality of well constants responsive to a value of the slope and of the intercept of the linear regression line. | 04-25-2013 |
20130131989 | APPARATUS AND COMPUTER READABLE MEDIUM FOR DETERMINING WELL CHARACTERISTICS AND PORE ARCHITECTURE UTILIZING CONVENTIONAL WELL LOGS - Apparatus, computer readable media, method and program code for determining well characterstics and pore architecture for a hydrocarbon well utilizing data available from conventional/standard electronic well logs, are provided. An example apparatus is configured to perform operations which include determining the value of well constants from well log data to include calculating water saturation, free water level location, wettability, and pore throat heterogeneity, and calculating/pore architecture at log resolution responsive thereto. This can be accomplished, for example, by accessing well log data from a conventional well log, determining a linear regression line responsive to parameters calculated from the well log data, the linear regression line having a slope and an intercept, and determining a value of each of a plurality of well constants responsive to a value of the slope and of the intercept of the linear regression line. | 05-23-2013 |
20130138348 | METHOD FOR DETERMINING THE PROFILE OF AN INFLOW AND THE PARAMETERS OF A WELL-SURROUNDING AREA IN A MULTIPAY WELL - A method for the determination of an inflow profile and bottom-hole area parameters (perforation zone parameters, bottom-hole area pollution parameters) in a multipay well comprises changing a production rate and measuring a temperature of a fluid flowing into the well as a function of time for each pay zone. Then a derivative of this temperature with respect to a logarithm of a time passed after the well production rate has been changed for each pay zone is determined. An inflow profile and other parameters are calculated based on a value of said derivative when it becomes constant and on a time after which the value of the derivative becomes constant. | 05-30-2013 |
20130138349 | METHOD AND APPARATUS FOR GROUNDWATER BASIN STORAGE TRACKING, REMEDIATION PERFORMANCE MONITORING AND OPTIMIZATION - A system for monitoring and display of representative parameters in a selected monitoring geography incorporates multiple sensor suites ( | 05-30-2013 |
20130144533 | APPARATUS AND METHOD OF MEASURING POROSITY AND PERMEABILITY OF DIOXIDE CARBON UNDERGROUND STORAGE MEDIUM - Disclosed are an apparatus and a method of measuring porosity and permeability of a carbon dioxide underground storage medium. Both of the porosity and the permeability are measured in the state that the confining pressure is applied once. The variation characteristic in the porosity and the permeability of the core sample according to the salt precipitation occurring when supercritical carbon dioxide is injected is continuously measured. The apparatus includes a holder receiving a core sample, a pressure pump applying a confining pressure to the core sample, a gas chamber storing gas and supplying supply the stored gas to the core sample, first to third pressure gauges measuring an internal pressure of the gas chamber and front and rear portions of the holder, and a gas flow meter measuring a flow rate of gas. | 06-06-2013 |
20130166216 | Determining Fluid Rate And Phase Information For A Hydrocarbon Well Using Predictive Models - A method of determining rate and phase of fluid produced from or injected into a hydrocarbon well includes obtaining first temperature and pressure measurements from sensors at the well. The first temperature and pressure measurements are applied to a plurality of predictive well models to calculate an estimated value of fluid rate and phase composition from each of the predictive well models responsive to the temperature and pressure measurements. A first fluid rate and phase composition result is derived from the estimate value of fluid rate and phase composition from each of the predictive well models. | 06-27-2013 |
20130173166 | TRACKING NON-UNIFORM FLOODING FRONTS OF GAS INJECTION IN OIL RESERVOIRS - Downhole gravity measurements are used to monitor the volumetric sweep of CO | 07-04-2013 |
20130173167 | Real-Time Dynamic Data Validation Methods For Intelligent Fields - Methods for managing an intelligent field, are provided. An exemplary method can 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 |
20130191030 | DETERMINING RESERVOIR CONNECTIVITY USING FLUID CONTACT GRAVITY MEASUREMENTS - An apparatus and method for estimating reservoir connectivity using gravity estimates at a fluid contact for each of two or more boreholes. The method may include identifying fluid contacts in the boreholes. The method may include additional gravity estimates at and/or between a well head and the fluid contact of each borehole. The method may include gravity estimates along a surface between well heads of the boreholes. The method may include estimating true vertical depth for the boreholes. The apparatus may include at least one gravimeter and a processor configured to estimate reservoir connectivity using estimates from the gravimeter. | 07-25-2013 |
20130197810 | MONITORING OF DRINKING WATER AQUIFERS DURING POSSIBLE CONTAMINATION OPERATIONS - A method and system for monitoring the integrity of a water aquifer is provided. The method and system generally monitors an aquifer for subsurface fractures, fluid intrusion, or water contamination. In one embodiment, the method and system may be utilized before, during, and after contaminating operations to monitor a water aquifer and generate reports detailing the effect of the contaminating operations on the water aquifer. The reports, and associated raw data, may be used as legal documents. For example, in one embodiment, an independent company is responsible for monitoring the aquifer and generating reports, which are then submitted to all interested parties, including the state for regulatory purposes. | 08-01-2013 |
20130211725 | POROSITY ESTIMATOR FOR FORMATE BRINE INVADED HYDROCARBON ZONE - A system and method estimate a property of an earth formation comprising hydrocarbon and non-hydrocarbon components. The method includes conveying a carrier down a borehole penetrating the earth formation, and performing a nuclear magnetic resonance (NMR) measurement on fluid in the earth formation with an NMR instrument disposed at the carrier to provide total NMR measurement data. The method also includes separating the total NMR measurement data into hydrocarbon-resultant NMR measurement data and non-hydrocarbon-resultant NMR measurement data, scaling a portion of the non-hydrocarbon-resultant NMR measurement data based on a correction factor to obtain scaled non-hydrocarbon-resultant NMR measurement data, and estimating the property based on the hydrocarbon-resultant NMR measurement data and the scaled non-hydrocarbon-resultant NMR measurement data. | 08-15-2013 |
20130231867 | SYSTEM AND METHOD FOR MODELING SHALE DISCONTINUITY - A method and system of locating discontinuities in a reservoir are provided. The method includes identifying a plurality of injection and production sites in the reservoir, injecting fluid into selected injection sites in accordance with an injection schedule, monitoring an output at the production sites, determining a time delay between the injection sites and the production sites based on the monitored output, and determining a location of discontinuities based on the determined time delay. | 09-05-2013 |
20130245952 | SYSTEM AND METHOD FOR CHARACTERIZING A FLOW PROPERTY OF A PRODUCTION WELL SITE IN A RESERVOIR - A method and system of characterizing a flow property of a production well site in a reservoir are provided. The method includes identifying a plurality of injection and production well sites in the reservoir; injecting fluid into selected injection well sites in accordance with an injection schedule; monitoring an output at the production well sites; determining a time delay between the selected injection sites and the production sites based on the monitored output using an estimated capacitance model; and characterizing a flow property of a production well site using the time delay and the estimated capacitance model. | 09-19-2013 |
20130253837 | METHODS FOR ESTIMATING MISSING REAL-TIME DATA FOR INTELLIGENT FIELDS - Methods for managing an intelligent field, are provided. An exemplary method can include, for example, the steps of receiving well instrument data, processing the data, detecting a missing or faulty data period, applying a rule set and logics, estimating values for the missing or faulty data, validating the estimated values, and inserting the data in the data period. | 09-26-2013 |
20130261979 | METHODS FOR DETERMINING WETTABILITY FROM NMR - Methods are described for wettability characterization based on NMR measurements, which are sensitive to the surface wetting conditions of oil and water at the pore scale. The described methods make use of surface relaxation effects on the NMR relaxation (T | 10-03-2013 |
20130317752 | AUTOMATIC FLUID CODING AND HYDRAULIC ZONE DETERMINATION - Systems, methods, and media for processing formation pressure test data are provided. The method includes determining using a processor, a plurality of regressions for measurements of the formation pressure test data, and determining that two or more of the plurality of regressions represent a fluid code. The method also includes combining the two or more of the plurality of regressions representing the fluid code to generate a first fluid-type regression, and combining two or more other ones of the plurality of regressions representing a second fluid code to generate a second fluid-type regression. The method further includes determining that the first fluid-type regression and the second fluid-type regression are in a first hydraulic zone, and calculating a location of a boundary between the first fluid-type regression and the second fluid-type regression by extrapolating the first and second fluid-type regressions to a point of intersection therebetween. | 11-28-2013 |
20130325351 | Smart Flowback Alarm to Detect Kicks and Losses - A method, apparatus and computer-readable medium for determining an influx at a wellbore is provided. A flowback parameter is obtained for a plurality of flowback events at the wellbore prior to a current flowback event. An average of the flowback parameter (μ) and a standard deviation (σ) of the flowback parameter is determined from the plurality of prior flowback parameters. An alarm threshold is set based on the determined average and the standard deviation. A current flowback parameter is measured and the influx is determined when the current flowback parameter meets the alarm threshold. | 12-05-2013 |
20140012507 | IN-WELL FULL-BORE MULTIPHASE FLOWMETER FOR HORIZONTAL WELLBORES - Methods and apparatus for measuring individual phase fractions and phase flow rates in a multiphase flow based on velocity of the flow, speed of sound through the fluid mixture, and the density of the fluid mixture. Techniques presented herein are based on measuring frictional pressure drop across a flowmeter conduit, determining a surface roughness term for the conduit during initial flow tests or through other mechanical means, implementing a correction method to balance the momentum equation, and calculating the fluid mixture density using the measured pressure drop. The techniques may be applicable to measuring flow parameters in horizontally oriented conduits and, more generally, conduits of any orientation. | 01-09-2014 |
20140019053 | Method For Evaluating Relative Permeability For Fractional Multi-Phase, Multi-Component Fluid Flow Through Porous Media - A method for computing or estimating relative permeability for fractional multi-phase, multi-component fluid flow through a porous medium, which employs a 3D digital representation of a porous medium and a computational fluid dynamics method to calculate flow rates, pressures, saturations, velocities and other flow parameters, is described. The method employs a unique method which integrates a precursor simulation used to generate a set of variables like pressure, saturation and velocity distribution associated with a selected storage plane in the 3D digital representation of a porous medium, which variables are used as inlet condition in the workflow of a second simulation that can generate values of fractional flow rates, pressures, saturations, velocities, or other parameters of wetting and non-wetting phases, which can be used to compute or estimate relative permeability values or other fluid transport properties of the porous medium. Computerized systems and programs for performing the method are also provided. | 01-16-2014 |
20140019054 | DIGITAL ROCK ANALYSIS SYSTEMS AND METHODS WITH RELIABLE MULTIPHASE PERMEABILITY DETERMINATION - The pore structure of rocks and other materials can be determined through microscopy and subjected to digital simulation to determine the properties of multiphase fluid flows through the material. To ensure reliable results, the digital rock model is first analyzed via a series of operations that, in some embodiments, include: obtaining a three-dimensional pore/matrix model of a sample; determining a flow axis; verifying that the dimension of the model along the flow axis exceeds that of a representative elementary volume (REV); selecting a flow direction; extending model by mirroring if pore statistics at a given saturation are mismatched for different percolating phases; and increasing resolution if the smallest nonpercolating sphere dimension is below a predetermined threshold. This sequence of operations increases reliability of results when measuring relative permeability using the model and displaying relative permeability measurements to user. | 01-16-2014 |
20140136116 | METHOD AND SYSTEM FOR PERMEABILITY CALCULATION USING PRODUCTION LOGS FOR HORIZONTAL WELLS - A method for permeability calculation includes determining fluid properties associated with a horizontal well, relative permeability to oil and relative permeability to water, for the horizontal well, and an approximate upper boundary and an approximate lower boundary of the horizontal well. In accordance with a particular embodiment, the horizontal well may be divided into a plurality of well segments. Actual production logging data associated with the horizontal well may be received at an interface. For each respective well segment, a horizontal permeability is calculated using the fluid properties, relative permeability to oil, relative permeability to water and actual production logging data. | 05-15-2014 |
20140136117 | METHOD AND SYSTEM FOR PERMEABILITY CALCULATION USING PRODUCTION LOGS FOR HORIZONTAL WELLS, USING A DOWNHOLE TOOL - A downhole tool for permeability calculation includes a body configured for insertion into and retraction from a horizontal well, and coupled with a computer system that includes an interface operable to receive (i) fluid properties associated with the horizontal well, under downhole production logging conditions; (ii) relative permeability to oil and relative permeability to water, for the horizontal well; and (iii) actual production logging data associated with the horizontal well. The computer system may also include one or more processors that are operable to (i) determine an approximate upper boundary and an approximate lower boundary of the horizontal well; (ii) divide the horizontal well into a plurality of well segments; and (iii) calculate, for each respective well segment, a horizontal permeability. | 05-15-2014 |
20140142857 | MEAN REGRESSION FUNCTION FOR PERMEABILITY - A method having obtaining one or more porosity data of a subsurface of the Earth using a data acquisition tool; computing one or more permeability data from the porosity data using a transformation function; computing a first quantile regression function and a second quantile regression function of the one or more permeability data; producing a combined mean regression function of the one or more permeability data by summing the first quantile regression function and the second quantile regression function, wherein the first quantile regression function is multiplied by a first coefficient and the second quantile regression function is multiplied by a second coefficient; and using the combined mean regression function to predict a mean permeability of the subsurface. | 05-22-2014 |
20140163889 | METHOD OF ACOUSTIC SURVEYING - The invention relates to the use of distributed optical fibre sensors for distributed acoustic sensing, and in particular, modal analysis of distributed acoustic data obtained in-well to monitoring well integrity. By determining one or more acoustic modes corresponding to distributed speed of sound measurements within the wellbore, and analysing variations in the distributed speed of sound measurement it is possible to derive information relating to a formation and/or fluid in the wellbore. | 06-12-2014 |
20140180592 | Downhole Fluid Tracking With Distributed Acoustic Sensing - Various disclosed distributed acoustic sensing (DAS) based systems and methods include embodiments that process the DAS measurements to detect one or more contrasts in acoustic signatures associated with one or more fluids flowing along a tubing string, and determine positions of the one or more contrasts as a function of time. The detected contrasts may be changes in acoustic signatures arising from one or more of: turbulence, frictional noise, acoustic attenuation, acoustic coupling, resonance frequency, resonance damping, and active noise generation by entrained materials. At least some of the contrasts correspond to interfaces between different fluids such as those that might be pumped during a cementing operation. Certain other method embodiments include acquiring DAS measurements along a borehole, processing the measurements to detect one or more acoustic signature contrasts associated with interfaces between different fluids in the borehole, and responsively displaying a position of at least one of said interfaces. | 06-26-2014 |
20140195161 | METHOD FOR DETERMINING THE COMPLEX RESPONSE OF A PERMEABLE STRATUM - A method for determining the complex response of a permeable stratum at the bottom of a producing well, the well comprising a well head fitted with an outlet valve and the bottom of the well comprising a height-adjustable pressure and flow rate sensor, comprising the following steps: periodically altering the degree to which the outlet valve is open, and, while the alteration is in progress:—measuring the pressure and flow rate in the well at the top/bottom of the stratum for a certain number of periods of alteration, after a certain delay; and—measuring the pressure and the flow rate in the well at the bottom/top of the stratum for a certain number of periods of alteration, immediately after the positioning of the sensor. | 07-10-2014 |
20140278112 | TESTING WATER CONTAMINATION AROUND OIL OR GAS WELLS - Testing water contamination around oil or gas wells. To determine a testing zone around an oil or gas well, multiple variables are received by data processing apparatus. The variables include variables associated with an oil or gas well, variables associated with an entity performing hydraulic fracturing in the oil or gas well, and variables associated with inhabitable regions surrounding the oil or gas well, to name a few. The multiple variables are processed by the data processing apparatus. In response to the processing, a zone around the oil or gas well within which to test for contamination due to the hydraulic fracturing in the oil or gas well is determined. | 09-18-2014 |
20140288836 | METHOD FOR DETERMINING THE INFLOW PROFILE OF FLUIDS OF MULTILAYER DEPOSITS - A method for determining the profile of fluids inflowing into multi-zone reservoirs provides for a temperature measurement in a wellbore during the return of the wellbore to thermal equilibrium after drilling and determining a temperature of the fluids inflowing into the wellbore from each pay zone after perforation at an initial stage of production. Specific flow rate for each pay zone is determined by a rate of change of the measured temperatures. | 09-25-2014 |
20140330522 | System and Method for Measuring Formation Properties - Pressure of a fluid in a geological formation is predicted using measured temperature and pressure changes following the creation of a pressure reduction in a flowline in fluid communication with the fluid in the geological formation. | 11-06-2014 |
20140336938 | METHODOLOGY FOR PRESENTING DUMPFLOOD DATA - A non-transitory computer-readable medium includes computer-executable instructions for presenting dumpflood data to a user by implementing steps on a computer. The steps include: receiving first data describing a first subsurface volume; receiving second data describing a second subsurface volume that is deeper than the first subsurface volume; calculating pressures required for a fluid to flow in a borehole from the first volume to the second volume as a function of vertical height of the first volume (h1), permeability of the first volume (k1), vertical height of the second volume (h2), permeability of the second volume (k2), a first damage factor (S1) representing damage to the first volume, and a second damage factor (S2) representing damage to the second volume; and displaying on a computer display a graphical representation of the calculated pressures and inputs used to calculate the pressures. | 11-13-2014 |
20140350860 | SYSTEMS, METHODS, AND COMPUTER-READABLE MEDIA FOR CONTINUOUS CAPILLARY PRESSURE ESTIMATION - Provided are methods, systems, and computer-readable media for determining capillary pressure in a basin/reservoir. Well log data is obtained that includes permeability log data, porosity log data, water saturation log data, and oil saturation log data. Thomeer parameters for a multi-pore system of a Thomeer model are determined by evaluating an objective function that measures the mismatch between the well log data and modeled data having the Thomeer parameters as input. The objective function is iteratively evaluated using linear equality constraints, linear inequality constraints, and nonlinear equality constraints until convergence criteria are met. | 11-27-2014 |
20140365130 | ESTIMATING FLOW RATES FROM MULTIPLE HYDROCARBON RESERVOIR LAYERS INTO A PRODUCTION WELL - There is provided a computer-implemented method for estimating flow of fluid into a production well extending into a reservoir comprising fluid, the well comprising a central tubing and an annulus surrounding the central tubing. The annulus is connected to the reservoir so as to receive fluid at one or more inflow locations. The central tubing has at least one inlet, arranged to allow fluid to flow from the annulus into the central tubing, and is located downstream of the one or more inflow locations. The production well further comprises one or more devices arranged to measure a temperature of fluid within the annulus at a plurality of points along the length of the annulus. The method comprises: receiving temperature data from the one or more devices indicative of a temperature of fluid at a plurality of points along the length of the annulus identifying a change in temperature of fluid flowing within the annulus on the basis of the received temperature data at the plurality of points; using a model to estimate heat transfer from the central tubing to fluid flowing within the annulus, said model being configured such that the heat transfer is assumed to be substantially constant along the length of the tubing; and estimating a rate at which fluid flows into the annulus from the reservoir at a first inflow location on the basis of the identified change in temperature between the points and the estimated heat transfer. | 12-11-2014 |
20140372042 | METHOD FOR OPTIMIZING THE WORKING OF A DEPOSIT OF FLUID BY TAKING INTO ACCOUNT A GEOLOGICAL AND TRANSITORY EXCHANGE TERM BETWEEN MATRIX BLOCKS AND FRACTURES - The invention is a method for optimizing working (EXP) of a deposit of fluid traversed by a network of fractures that involves determining the transitory exchange terms between matrix blocks and fractures (FFA, FFN), for any type of available information (INFO) concerning the network of fractures, regardless of the level of knowledge of the fractured environment. | 12-18-2014 |
20150039235 | PERMEABILITY PREDICTION SYSTEMS AND METHODS USING QUADRATIC DISCRIMINANT ANALYSIS - Permeability prediction systems and methods using quadratic discriminant analysis are presented. At least one disclosed method embodiment includes: acquiring formation property measurements at a plurality of positions along at least one borehole in a study area; identifying clusters in a plurality of points representing the formation property measurements at the plurality of postions; and determining a system permeability value for each cluster. Quadratic Discriminant Analysis (“QDA”) is used to associate one the clusters with each position along the one or more boreholes, thereby determining a system permeability prediction for each position. The total system permeability can then be predicted by aggregating the system permeability predictions. | 02-05-2015 |
20150057935 | MODIFIED FLOW RATE ANALYSIS - Methods, systems, devices, and products for estimating a parameter of interest of an earth formation. The method may include using a correction factor to conduct a flow rate analysis on fluid sampled from the formation via a probe contacting a wall of the borehole, wherein the correction factor compensates for total compressibility; determining at least one of: i) the product of formation porosity and total compressibility; ii) system compressibility; and iii) initial formation pressure; or determining a mobility of the formation using a slope of a linear relationship of a time-dependent pressure of the fluid with respect to a formation flow rate. The parameter of interest may be i) formation mobility or ii) formation permeability. The correction factor may be determined using formation compressibility. The correction factor may be determined using at least one of: i) gas saturation; ii) oil saturation; and iii) water saturation. | 02-26-2015 |
20150066372 | METHOD AND SYSTEM FOR ANALYZING AND PROCESSING CONTINUED FLOW DATA IN WELL TESTING DATA - Methods and systems analyze continued flow data in well testing data. Embodiments can determine relations between an isochron rate and influence factors under pre-detected lithologic conditions, acquire relational data between the isochron rate and the lithology of a reservoir, the structure of the reservoir, and fluid properties; establish a mathematical model of the isochron rate; collect bottom hole pressure at different collection moments respectively during the reservoir well testing process; acquire a measured isochron rate curve between the isochron rate V | 03-05-2015 |
20150112599 | DETERMINING THE QUALITY OF DATA GATHERED IN A WELLBORE IN A SUBTERRANEAN FORMATION - Methods for determining the quality of data gathered in a wellbore in a subterranean formation including (a) collecting a formation fluid sample in the wellbore in the subterranean formation using a formation tester for receiving the formation fluid, wherein the formation tester is lowered to at least one depth in the wellbore in the subterranean formation by a conveyor; (b) acquiring a wellbore measurement (“WM”) from the least one depth with the formation tester; (c) determining from the WM a measured quality value (“MQV”); (d) assigning a threshold value (“TV”) to the MQV; (e) assigning a range value (“RV”) to the MQV, based on geometric scaling of the TV, the RV defining the limits of the MQV above and below the TV; and (f) calculating a score value (“SV”) based on the MQV, the TV, and the RV, wherein the SV is a number between 0 and 2*TV, and wherein the quality of the WM increases as the SV increases. | 04-23-2015 |
20150142321 | Flow Rate From Displacement Unit Piston Position - A method to detect flow rate from a displacement unit entailing locating the displacement unit in a fluid path, monitoring a piston position in the displacement unit for a stroke direction change, starting a timer upon a stroke direction change, monitoring at least one check valve position for an alteration of position, stopping the timer upon the alteration of position, calculating a time between the stroke direction change and the alternation of position, calculating a volume of the displacement unit and calculating the flow rate from the displacement unit by dividing the volume of the displacement unit by the calculated time. | 05-21-2015 |
20150322773 | FLOW MANAGEMENT SYSTEM AND METHOD - A monitoring tool is provided for monitoring wells for flow anomalies. The temperatures of flowing well fluid and ambient temperature are monitored and various methods applied to indicate if a well is flowing as expected, is flowing less than expected and, therefore, at risk of flow stoppage, not flowing or calculation of flow rate when the well is flowing less than expected. Approaches are described for determining trending indicators from actual flow temperatures compared to a normal flow relationship for establishing the presence of flow anomalies. Temperature sensors, onsite processors and communications upload data for display of well status flags on a mapping module enabling pro-active detection and preventative action by operators. | 11-12-2015 |
20150322775 | SYSTEMS AND METHODS FOR MONITORING WELLBORE FLUIDS USING MICROANALYSIS OF REAL-TIME PUMPING DATA - Systems and methods for obtaining information about one or more fluids in a wellbore in a subterranean formation are disclosed herein. A fluid monitoring system comprises a fluid measurement device and a data system that receives a first and second set of data. A first set of data and second set of data may be obtained and compared to determine the location of one or more fluids in a wellbore in real time. | 11-12-2015 |
20150369957 | Generating Relative Permeabilities and Capillary Pressures - An apparatus is operated to obtain a model predicting data associated with a theoretical sampling operation to be performed by a downhole sampling tool, including predicted water-cut and pressure data relative to time elapsed during the theoretical sampling operation. The model predicts the water-cut and pressure data based on estimated relative permeability and capillary pressure related to different constituents of fluid theoretically obtained from a subterranean formation by the downhole sampling tool during the theoretical sampling operation. An actual sampling operation is performed with the downhole sampling tool to actually obtain fluid and data associated with the actually obtained fluid, including actual water-cut and drawdown pressure data. The apparatus is then operated to update the model utilizing the actual data water-cut and drawdown pressure data, thus obtaining actual relative permeability and capillary pressure data. | 12-24-2015 |
20160010451 | Flow Meter Well Tool | 01-14-2016 |
20160024911 | Advanced Perforation Modeling - A technique is provided for modeling flow simulations at downhole reservoir conditions and rock formations after performing wellbore perforations. By utilizing these flow simulations, a user may be able to simulate and compare different scenarios, thereby facilitating a more effective, profitable, and realistic choice of perforating systems and operating conditions. | 01-28-2016 |
20160077228 | IMPROVEMENTS IN DETERMINING SUB-SURFACE TEMPERATURE - There is described a technique for determining a temperature at a region below the surface of the Earth. In an embodiment, a time of travel of a seismic wave following the emission from a source into the earth is provided, and the travel time is used to estimate the temperature. In one example, a model based on the travel time and a further component, which may for example be based on heat flow and a constant of proportionality between seismic velocity and thermal conductivity, may be used to estimate the temperature. | 03-17-2016 |
20160090836 | Flow Regime Identification with Filtrate Contamination Monitoring - A method includes operating a downhole acquisition tool in a wellbore in a geological formation. The wellbore or the geological formation, or both contains a fluid that includes a native reservoir fluid of the geological formation and a contaminant. The method also includes receiving a portion of the fluid into the downhole acquisition tool, measuring a fluid property of the portion of the fluid using the downhole acquisition tool, and using the processor to estimate a fluid property of the native reservoir fluid based on the measured fluid property of the portion of the fluid and a regression model that may predict an asymptote of a growth curve. The asymptote corresponds to the estimated fluid property of the native formation fluid, and the regression model includes a geometric fitting model other than a power-law model. | 03-31-2016 |
20160108729 | METHOD AND DEVICE FOR THE CONCURRENT DETERMINATION OF FLUID DENSITY AND VISCOSITY IN-SITU - A measurement device and method for determining the density and viscosity of a fluid in a downhole environment from vibration frequencies of a sample cavity. | 04-21-2016 |
20160177707 | Determining Resonance Frequency and Quality Factor | 06-23-2016 |
20160178800 | STATIC EARTH MODEL CALIBRATION METHODS AND SYSTEMS USING PERMEABILITY TESTING | 06-23-2016 |
20160187532 | METHODS FOR DETERMINING A SATURATION-HEIGHT FUNCTION IN OIL AND GAS RESERVOIRS - Saturation-height functions in oil and gas reservoirs are determined using methods that include quantifying the microporosity of the subterranean formation; determining the distribution of facies and microporosity as a function of depth; and calculating the saturation-height function for a given formation. | 06-30-2016 |
20160376885 | Method and Apparatus for Performance Prediction of Multi-Layered Oil Reservoirs - The present invention discloses a method and an apparatus for predicting performance profiles of multi-layered oil reservoirs, wherein the method comprises: dividing the multi-layered oil reservoirs into a plurality of blocks, and determining a reservoir type, formation factor Kh and an evaluated reserves of each layer in each block; selecting a block representing geologic features of the multi-layered oil reservoirs from the plurality of blocks as a representative block, to build a fine geological model of the representative block; building corresponding fine numerical simulation model according to the fine geological model of the representative block, and determining type curves of different reservoir types under different development strategies; determining a relation curve between Kh and well injection rate for injectors and a relation curve between Kh and well production rate for producers in the multi-layered oil reservoirs under different restrictive conditions; predicting performance of the multi-layered oil reservoirs according to the type curve, the relation curve between Kh and well injection rate, the relation curve between Kh and well production rate, and the reservoir type, formation factor Kh and evaluated reserves of each layer in each block. | 12-29-2016 |