Abstract: A dedicated liquid level detection method having a sensor positioned into the casing of a groundwater well. The detector is in the form of an elongated thin film sensor tape that extends along the fill length of the well casing which detects the level, thickness and volume of both groundwater and any light or dense non-aqueous phase liquid that may be present. This is accomplished through the use of a conductive and hydrostatic resistive circuit measuring the level of liquids in a groundwater well at one hundredths of foot resolution or greater. Once the elongated sensor is installed, liquid levels can be gauged from the surface. The data is stored using a battery operated hand held digital display temporarily connected at the top well section casing. Since a sensor probe is not lowered into the well, cross contamination between wells is eliminated.

Abstract: A system which receives as inputs various measurements of solids and liquids in a clarification system and, from these measurements, determines the various constituents and their fractional makeup within the system. The measurements may be made manually or mechanically, but are preferably made manually. From a quantitative analysis of easily accessible sample points, data is acquired and plugged into a spread sheet program, which numerically and graphically displays the breakdown of the constituents which make up the solids and liquids discharged from a treatment stage or of the entire system.

Abstract: A flow cell for examining specimen fluid flowing within sheath fluid. A housing defines a hollow fluid passage that includes a geometric focusing portion in which the fluid passage narrows in height and an examination area. A cannula injects specimen fluid into the fluid passage as a stream of the specimen fluid with an initial velocity. The sheath fluid flows through the fluid passage, having a first velocity as it passes the point the specimen fluid is injected. The initial velocity is less than the first velocity, which focuses down the height of the specimen fluid stream via linear flow rate focusing. The narrowing geometric focusing portion of the fluid passage also focuses down the height of the specimen fluid stream via geometric focusing. A microscope and camera capture images of the focused down specimen fluid stream passing through the examination area.

Abstract: The present invention provides a chemometric equation to estimate fluid density, viscosity, dielectric constant and resistivity for a formation fluid sample downhole. The chemometric estimates can be used directly as estimated values for fluid density, viscosity, dielectric constant and resistivity for a formation fluid sample downhole. The chemometric estimates can also be plugged into a Levenberg-Marquardt (LM) non-linear least squares fit, as an initial estimate of the parameter to be estimated by the LM fit. If the initial parameter estimate is too far from the actual parameter values, the LM algorithm may take a long time to converge or even fail to converge entirely. The present invention estimates an initial value of a parameter that provides a high probability that the LM algorithm will converge to a global minimum.

Abstract: A method providing real-time determination of a thermal profile of the drilling fluid in a well from three measuring points available in the field, i.e. the injection temperature, the outlet temperature and the bottomhole temperature is disclosed. The form of the profile between these three points is defined by a type curve representative of the thermal profiles in a well under drilling, estimated from physical considerations on thermal transfers in the well.

Abstract: A method of and product for use in cementing the annulus of a hydrocarbon well having a casing centered within a hole bored from a surface. The method comprises the steps of introducing an effective amount of colouring agent contained in a water-soluble bag into a portion of spacer or scavenging fluid, pumping the spacer or scavenger and a then cementing slurry down the casing to the bottom of the hole to displace drilling mud upwardly through the annulus to the surface, until the colouring agent becomes visible at the surface, displacing the casing volume and then stopping the pumping and allowing the pumped cement slurry to harden.

Abstract: The present invention discloses an acoustic resonator device capable of nucleating bubbles in a formation fluid under borehole-like conditions wherein the static pressure is higher than the bubble point pressure. The device is comprised of one or more coaxial layers forming a central conduit, wherein at least one of the coaxial layers is comprised of an electro-acoustic transducer material such as including piezoelectric or magnetorestrictive materials. This device is preferably designed to be in fluid communication with a host tool to allow in-situ sampling and bubble point determination. Also disclosed is an in-situ method of fluid analysis in a borehole for determining phase characteristics of a formation fluid using the device. Cavitation may be induced using the device in either a captured volume sample or a flow-line sample.

Abstract: A monitoring system for monitoring resources such as water in a bore having an air column extending from a wellhead to a surface level and a resource column extending from the surface level to an extraction inlet includes a sensor unit and a base unit. The sensor unit includes a sensor mounted within the bore and including a transmitting unit for transmitting at least a single sound pulse formed of a pulsed sinusoidal waveform into the bore and a receiving unit for receiving a return signal representing the single sound pulse reflected from the water surface level. The base unit uses the measured round trip time to determine an air column length from the sensor to the water surface level and a water column length from the water surface level to the extraction inlet and, from a cross sectional area of the bore, a water resource value representing a volume of water contained between the water surface level and the extraction inlet.

Abstract: An oil pressure switch failure detection system for an outboard motor, having a first oil pressure switch which generates an ON signal indicating that the oil pressure is less than or equal to a first predetermined oil pressure and a second oil pressure switch which generates an ON signal indicating that the oil pressure is less than or equal to a second predetermined oil pressure which is set higher than the first predetermined oil pressure. In the system, by discriminating whether the generated signals of the first and second oil pressure switches are equal to be expected signals expected under operating conditions of the engine, it is determined whether at least one of the first and second oil pressure switches fails. With this, it become possible to detect failure of the first and second oil pressure switches, accurately.

Abstract: A method is disclosed for determining viscosity and density of fluid from formations surrounding an earth borehole, including the following steps: (a) suspending a formation testing device in the borehole; (b) drawing formation fluid into the device; (c) causing the fluid to flow in a flow line under a first set of conditions; (d) causing the fluid to flow in the flow line under a second set of conditions; (e) measuring a first fluid pressure differential in the flow line during fluid flow under the first set of conditions, and measuring a second pressure differential in the flow line during fluid flow under the second set of conditions; and (f) determining density and viscosity of the fluid as a function of the first and second measured pressure differentials.

Abstract: The present invention discloses a method and apparatus to detect bubbles in a fluid sample to determine if gases are present, wherein an ultrasonic source is used and its properties monitored. Fluctuations in the ultrasonic source's electrical properties indicate the presence of bubbles/gas. Alternatively, the ultrasonic source may be used to cavitate the sample and induce the nucleation of bubbles. In such a system/method, bubbles may be detected by either (1) monitoring the ultrasonic source properties, (2) monitoring the compressibility of the sample, (3) monitoring the sample properties, including harmonics and subharmonics. The method and apparatus disclosed herein may be used in a borehole such as with a sampling means (including either a flowing sample or a stationary sample) or in a surface lab.

Abstract: A downhole tool and method for determining the viscosity of a reservoir fluid, the tool including a passage having entry, intermediate and exit regions, in which the reservoir fluid flowing through the passage will have a lower Reynolds number in the intermediate region as compared to the entry region, the tool also including differential pressure gauge for measuring the differential pressure across the intermediate region, and either a velocity controller or fluid velocity meter, for either setting or measuring the fluid velocity.

Abstract: The invention concerns a method of sampling the formation fluids in an earth formation surrounding a borehole, the region of the formation immediately surrounding the borehole being at least partially invaded by borehole fluids, and an apparatus for carrying out such a method. According to the invention, a borehole tool is adapted to be lowered into the borehole and is provided with a sampling probe device and means for urging the sampling probe device into contact with the borehole wall, the sampling probe device comprising an inner probe and an outer probe surrounding the inner probe for withdrawing respective fluid samples from the formation, wherein the ratio between the respective flow areas of the inner and outer probes is selected so as to tend to reduce the time taken to obtain via the inner probe a sample of the formation fluids having a given level of contamination by borehole fluids.

Abstract: A computer-implemented method of calculating various types of characteristic curves of a centrifugal fluid machine according to the present invention can easily calculate a Q-H characteristic curve, a Q-E characteristic curve, a Q-NPSH characteristic curve, or the like. The method of calculating various types of characteristic curves uses two prescribed characteristic curves Y1=a11+a12x+a13x2+ . . . +a1nx(n−1) and Y2=a21+a22x+a23x2+ . . . +a2nx(n−1) formed of high-order equations for a centrifugal fluid machine to calculate a characteristic curve Y3=b1+b2x+b3x2+ . . . +bnx(n−1) formed of a high-order equation which passes through different coordinates (x3, y3).

Abstract: An operating well of a fluid storage reserve, includes an outer wall delimiting, with a central operating tubing of the well, an annular space in which is placed a protective sheath of an electrical link cable between a surface installation and elements arranged in the well. A device for the measurement of physical parameters includes at least one compact, removable, sealed measuring subassembly arranged in a housing in communication with the interior of the central tubing and at least one compact, sealed connecting subassembly integral with the central tubing of the well and arranged at least partially in the annular space in the vicinity of the protective sheath to be connected to the electrical link cable. The sealed measuring subassembly and the sealed connecting subassembly have plane contact surfaces, each associated with a half-transformer so as to form an inductive coupling between the measuring subassembly and the connecting subassembly.

Abstract: A minimum volume apparatus and method is provided including a tool for obtaining at least one parameter of interest of a subterranean formation in-situ, the tool comprising a carrier member, a selectively extendable member mounted on the carrier for isolating a portion of annulus, a port exposable to formation fluid in the isolated annulus space, a piston integrally disposed within the extendable member for urging the fluid into the port, and a sensor operatively associated with the port for detecting at least one parameter of interest of the fluid.

Abstract: A fiber optic sensor system provides sufficient thermal information to determine the mass flow rates of produced fluids within a well bore, using an optical fiber placed within or adjacent to the well bore without interference with production or prejudicing the integrity of the well. Mass flow rates of fluid in a conduit (20) located in a heat sink differing in temperature from the fluid are determined by obtaining a distributed temperature profile (32) of fluid flowing along a length of conduit (15) by using optical data obtained from a length of optical fiber in thermal contact therewith, obtaining a profile of the heat sink temperature external to the conduit, and deriving mass flow rates of fluids in the conduit from the said profiles and from measured thermal transfer parameters.

Abstract: A method and apparatus for in-situ characterization of downhole fluids in a wellbore using ultrasonic acoustic signals. Measurements of the speed of sound, attenuation of the signal, and acoustic back-scattering are used to provide qualitative and quantitative data as to the composition, nature of solid particulates, compressibility, bubble point, and the oil/water ratio of the fluid. The tool generally comprises three sets of acoustic transducers mounted perpendicular to the direction of the flow. These transducers are capable of operating at different frequencies so that the spectrum of the acoustic signal can be optimized. The apparatus is capable of operating downhole to provide real time information as to conditions in the well.

Abstract: A compensated flow measuring system for measuring a multi-phase fluid flow in a well. An impeller intercepts a downhole multi-phase flow. Capacitance and conductivity sensors are mounted in close proximity to the impeller and provide a measure of electrical admittance of the fluid. In one embodiment, the capacitance and conductivity sensors are mounted in at least one single probe mounted near the impeller. An electronics system contains a phase detector for separating the capacitive and conductive signals and providing a signal related to a compensated multiphase flow rate.

Abstract: A Vadose Zone Water Fluxmeter (WFM) or Direct Measurement WFM provides direct measurement of unsaturated water flow in the vadose zone. The fluxmeter is a cylindrical device that fits in a borehole or can be installed near the surface, or in pits, or in pile structures. The fluxmeter is primarily a combination of tensiometers and a porous element or plate in a water cell that is used for water injection or extraction under field conditions. The same water pressure measured outside and inside of the soil sheltered by the lower cylinder of the fluxmeter indicates that the water flux through the lower cylinder is similar to the water flux in the surrounding soil. The fluxmeter provides direct measurement of the water flow rate in the unsaturated soils and then determines the water flux, i.e. the water flow rate per unit area.

Abstract: A method of identifying the fluid type of subterranean formations according to the correlation between the variation trend of electrical resistivity with depth downhole in a borehole and the variation trend of porosity with depth downhole in the same borehole. The method includes the steps of: a) determining the rate of change with depth of a resistivity parameter (such as deep resistivity) of the formation surrounding the borehole; b) determining the rate of change with depth of a porosity parameter (such as total porosity and/or free fluid porosity measured by a nuclear magnetic resonance technique) of the formation surrounding the borehole; c) determining a comparison of the rate of change with depth of such resistivity parameter and the rate of change with depth of such porosity parameter for a given depth in the borehole; and d) using the comparison to determine the nature of the fluid in the formation surrounding the borehole at that depth downhole or in a given depth window downhole.

Abstract: An apparatus and method for monitoring and characterizing the fluid flow in and around the tubing string in a wellbore, preferably using fiber optic componentry. The apparatus includes a signal sensing demodulator device and a skin friction sensing device positionable within the wellbore. Both devices are in informational communication with each other. The method includes exposing the skin friction sensing device to a fluid flow, transmitting a signal obtained as a result of a movement of the skin friction sensing device from the fluid flow to a signal sensing demodulator device, converting the signal to a numerical value, and computing a parameter or parameters of the fluid flow in the wellbore from the numerical value.

Abstract: An apparatus is provided comprising a first tubular having an inside surface and outside surface defining an outside diameter; a second tubular concentric with the first tubular, the second tubular having an inside surface defining an inside diameter greater than the outside diameter of the first tubular, an outside surface, and a longitudinal axis; a plurality of spacers between the first and second tubulars, each spacer having a longitudinal axis parallel to the longitudinal axis of the second tubular, wherein at least one spacer is hollow; and at least one data sensing device and/or at least one data collecting device and/or at least one data transmitting device is carried within the at least one hollow spacer.

Abstract: For collecting data from a water well, down-hole sensors are housed in modules. The modules are arranged to be screwed together in-line to form a vertical string. Mechanically, the modules are secured to each other only by the screw connection. Data is transmitted to the surface on a 2-wire cable, there being no other electrical connection between the modules and the surface. The modules are connected In multi-drop configuration to the 2-wire cable. Data is transmitted using time-division multiplexing.

Abstract: The device includes a pipe section in loop form having two arms which make an angle with the horizontal, which arms each contain two pressure sensors which are located some distance apart in the direction of flow, as well as a processing unit, connected to the pressure sensors, for determining the density of the medium on the basis of the pressures or an associated parameter measured by the sensors. The pipe section in loop form is connected in parallel to the pipeline.

Abstract: For collecting data from a water well, down-hole sensors are housed in modules. The modules are arranged to be screwed together in-line to form a vertical string. Mechanically, the modules are secured to each other only by the screw connection. Data is transmitted to the surface on a 2-wire cable, there being no other electrical connection between the modules and the surface. The modules are connected in multi-drop configuration to the 2-wire cable. Data is transmitted using time-division multiplexing.

Abstract: A dedicated liquid level detection method having a sensor positioned into the casing of a groundwater well. The detector is in the form of an elongated thin film sensor tape that extends along the fill length of the well casing which detects the level, thickness and volume of both groundwater and any light or dense non-aqueous phase liquid that may be present. This is accomplished through the use of a conductive and hydrostatic resistive circuit measuring the level of liquids in a groundwater well at one hundredths of foot resolution or greater. Once the elongated sensor is installed, liquid levels can be gauged from the surface. The data is stored using a battery operated hand held digital display temporarily connected at the top well section casing. Since a sensor probe is not lowered into the well, cross contamination between wells is eliminated.

Abstract: A receptacle (10) for use in collecting samples down a well bore (14) is provided, the receptacle comprising a plurality of interconnecting modules (22, 24, 26, 30, 32, 34). A main chamber (22) is capable of holding a sample, and sensors (58, 60, 62, 64) within the chamber detect physical and chemical characteristics of the sample. Valves (50, 52) in a chamber wall seal the chamber (22) after a fluid sample has been collected. A communication means is placed in communication with the chamber (22) so as to provide an externally accessible port which communicates with the inside of the chamber (22) and allows detection and analysis of sample characteristics without removing the sample from the sealed chamber (22). The chamber (22) includes a piston (82) which is adjustable to keep pressure constant in the chamber and a heating element (58) to keep temperature constant. A method for sampling downhole fluids is also provided.

Abstract: A well tester adapted to select among members of an oil well family to provide a purged and clean vessel to receive samples of well production that include gas and oil, and by selective use of production pressure and lease water under pressure, allow for the separation and separate measure of the oil and gas, and optionally to provide for improved sampling of production fluids with high gas/oil ratios.

Abstract: In a borehole logging tool, the flow of conductive fluid into or out of a wellbore at the wellbore wall is detected and measured with a sensor loop proximate the borehole inner wall. The sensor loop includes a series of contiguous sensors that act as electromagnetic flowmeters and provide fluid measurements covering the entire circumference of the sensor loop. The sensor loop includes an elastic element that forces the sensor loop outward to maintain pressure along the sensor loop circumference against the interior borehole wall. The sensor loop is designed to lie at a non-perpendicular angle to the wellbore axis, and mechanical arms press the top and bottom of the loop against the borehole inner wall.

Abstract: A system and method of fluid analysis in a hydrocarbon borehole is disclosed. Acoustic energy is emitted into the production fluid downhole at a level which causes a phase transition in the fluid. The pressure associated with the phase transition is determined using the level of emitted acoustic energy. Advantageously, the determination of the phase transition pressure need not rely on mechanical means to substantially alter the volume of a sample of the fluid. An acoustic transducer can be installed either semi-permanently or permanently downhole in the well. The bubble point or the dew point can be detected. In the case of bubble point detection, the bubbles in the fluid can be detected by sensing variations in impedance of the acoustic transducer, and the level of emitted acoustic energy can determined by measuring the electrical energy used to drive the transducer. A control system for a hydrocarbon well is also disclosed.

Abstract: Systems and methods particularly suitable for open hole formation testing are provided. In a described embodiment, a method of performing a test on a formation intersected by a wellbore includes the steps of flowing fluid into an apparatus from the formation, displacing a fluid barrier of the apparatus in one direction, flowing the formation fluid out of the apparatus and back into the formation by applying pressure to the apparatus, and displacing the fluid barrier in an opposite direction.

Abstract: A minimum volume apparatus and method is provided including a tool for obtaining at least one parameter of interest of a subterranean formation in-situ, the tool comprising a carrier member, a selectively extendable member mounted on the carrier for isolating a portion of annulus, a port exposable to formation fluid in the isolated annulus space, a piston integrally disposed within the extendable member for urging the fluid into the port, and a sensor operatively associated with the port for detecting at least one parameter of interest of the fluid.

Abstract: The compressibility of a formation hydrocarbon sample is determined downhole by using a borehole tool to obtain the sample downhole, and, at two different pressures, subjecting the sample to near infrared illumination and conducting spectral absorption measurement of peaks at and/or around about 6,000 cm−1 and/or at and/or about 5,800 cm−1 (the absorption peaks of methane and crude oil respectively). The compressibility of the sample is determined from the change in the peak areas, the change in pressure, and the measured peak area itself. According to a preferred embodiment of the invention, the pressure is changed at least 2000 pounds per square inch (psi), and preferably 4000 or more psi between measurements.

Abstract: The present invention provides a system that monitors and controls the precipitation of asphaltenes in a formation fluid recovered from a subsurface formation or reservoir by using a sensor to make a direct real-time on-site measurement of the relative concentration asphaltenes from at least one location at a wellsite or in a pipeline. In a system including a fiber optic attenuated total reflectance probe for sensing asphaltenes and using a processor to compare sequential measurements, the system of the present invention can trigger the addition of additives in response to a change in asphaltene concentration in the formation fluid, preventing precipitation.

Abstract: A method and apparatus for retrieving magnetic casing fragments from a well using a shrouded magnet are disclosed. Retrieving casing fragments allows the determination of weight loss from the casing to assist in analyzing the integrity of the casing and to determine whether more expensive analysis is required. The shrouded magnet, a non-magnetic container enclosing a source of magnetic field, recovers metal casing fragments, which fragments are easily separated from the device by removing the source of magnetic field from the container.

Abstract: A method and apparatus for retrieving magnetic casing fragments from a well using a shrouded magnet are disclosed. Retrieving casing fragments allows the determination of weight loss from the casing to assist in analyzing the integrity and the condition of the casing and to determine whether more expensive analysis is required. The shrouded magnet, that is formed by a non-magnetic container enclosing a source of magnetic field, recovers metal casing fragments by attracting them and other magnetic materials from oil and gas well fluids passing by the shrouded magnet device, which fragments are easily separated from the device by removing the source of magnetic field from the container.

Abstract: A fluid analyzer including a physical property value setting section 2 for setting a physical property value in accordance with grid information for boundary conditions and object positions, a number-of-dimension control section 5 for controlling the number of dimensions of a space to be analyzed, a momentum correction section 51 for automatically correcting the momentum of the speed vector of an inlet or outlet, and a boundary condition control section 4 for automatically setting a boundary condition not diverged even in natural convection computation, which repeats repetitive computation until resulting in convergence after generating grids. Thereby, it is possible to accurately set a physical property value and an analysis dimension according to grid division, correct a momentum, and control natural convection computation.

Abstract: A downhole apparatus (100) for determining the constituent composition of a produced fluid is disclosed. The apparatus (100) includes a vessel (106) having an interior chamber (108) that receives and contains a sample of the produced fluid. In the interior chamber (108), the sample of the produced fluid is allowed to separate into its constituents. A gauge (200) having an array of transmitter elements (E1-E17) and an array of corresponding receiver elements (R1-R17) disposed oppositely of one another on the vessel (106), is used to transmit and receive energy waves that propagate through the sample of the produced fluid. The receiver elements (R1-R17) detect changes in absorption or scattering of the energy waves transmitted from the corresponding transmitter element (E1-E17) caused by the constituent of the sample of the produced fluid through which that energy wave propagated.

Abstract: A self-contained, transportable system for conducting any of hydrologic tests or water sampling techniques without the need for retooling or readjusting the system. The system includes a borehole unit for conducting the tests in a borehole, and a data acquisition unit for monitoring and recording the results of the tests. The borehole unit includes, connected in serial relation, a pair of borehole packers for forcing the unit in place in the borehole, several pressure transducers for obtaining hydraulic measurements, a pump located between the borehole packers for withdrawing fluid and a fluid injector for injecting fluid. The data-acquisition system includes flow meters for monitoring fluid injection and fluid withdrawals, a data-acquisition module for monitoring fluid pressure from the pressure transducers, power source and a computer interface.

Abstract: An apparatus for non-intrusively sensing fluid flow within a pipe is provided. The apparatus includes a first sensing array for sensing acoustic signals traveling at the speed of sound through fluid flow within the pipe, a second sensing array for sensing local pressure variations traveling with the fluid flow, and a housing attached to the pipe for enclosing the sensing arrays. The first sensing array includes a plurality of first optical pressure sensors and the second sensing array includes a plurality of second optical pressure sensors.

Abstract: An improved method to detect water influx using video monitoring of a cased wellbore is disclosed. A wireline well tool having a video camera and a light source is lowered into a selected borehole interval where water influx is suspected. The borehole fluid over the selected interval is displaced and replaced with either a water transparent mixture containing a viscosifying agent, a coloring agent and/or sufficient salt to increase mixture density; or a transparent water insoluble solvent. By use of either of these displacement fluids, the quality of video monitoring over the selected borehole interval for water influx, is enhanced.

Abstract: A monitoring system determines characteristics of a fluid in a well. The system comprises a well module adapted to be disposed in a well, where the module comprises a probe and at least one sensor that senses characteristics of the fluid. The well module is capable of transmitting information concerning fluid characteristics. The system further comprises a data collection center, which is capable of receiving well information from the well module and generating information concerning characteristics of the fluid, a monitoring site, and a communication link that enables a user at the monitoring site to obtain information such as, but not limited to, real-time, historical, and a combination of real-time and historical concerning the characteristics.

Abstract: A mud pulse telemetry adaptive noise canceler (ANC) employs a primary transducer and a reference transducer downstream from a position of the primary transducer. The primary transducer receives a primary signal based on a combination of a transmitted pulse and a reflected pulse, and the reference transducer receives a reference signal based on the transmitted pulse. The ANC linearly relates the secondary signal to the primary signal by means of a fast recursive least squares algorithm and calculates a set of weighting coefficients. The finite impulse response (FIR) filter of the ANC uses the set of weighting coefficients to adaptively noise cancel correlated portions between the primary signal and the secondary signal to produce an ANC output signal based on uncorrelated portions between the primary signal and the secondary signal.

Abstract: A well assembly for extracting production fluids from at least one production zone of at least one well includes a production pipe for transporting fluid downstream to a surface, a packer for defining the production zone, and a fiber optic sensor package disposed substantially adjacent to a downstream side of the packer. The fiber optic sensor package measures parameters of the production fluid and communicates these parameters to the surface to determine composition of the production fluid entering the production pipe through each production zone. The production pipe has a zone opening for allowing the production fluid to enter the production pipe and a control valve for controlling the amount of production fluid flowing downstream from each production zone. The production pipe control valve is adjusted to optimize fluid production from the particular production zone of the well based on fluid parameters measured by the fiber optic sensor package.

Abstract: A system for evaluating multiphase fluid flow in a wellbore. Two distinct AC signals are injected into a fluid. One AC signal originates from a transmitter electrode in ohmic contact with the fluid, and the other AC signal originates from a transmitter electrode capacitively coupled to the fluid. The geometric factors between the electrode pairs are selected to distinguish between different constituents within the wellbore fluids. The output electrical impedance of the ohmic transmitter is low so that the AC signal from the capacitive transmitter is shunted to signal ground in electrically conductive fluids. A single detector can measure the fraction of electrically conductive water covering the detector electrode as well as the dielectric constant of an oil and gas mixture. Arrays of such detector electrodes can measure the holdups and velocities of the constituent fluids in a flowing multiphase fluid.

Abstract: A method is provided for determining the actual inflow rates of gas and liquid into a wellbore from a reservoir. The wellhead is first closed and the wellhead pressure is measured over time. For a briefly period, gas is flowed from the wellhead and the wellhead pressure is measured again. Using the two conditions, the original wellbore gas volume and an original fluid inflow rate is determined. Gas is again flowed from the wellhead, both the flow and the pressure being measured, but this time for a prolonged duration, sufficient to affect the reservoir. Assuming original gas inflow rate and original gas volume remain unchanged during the prolonged flow, a total rate of fluid inflow from the reservoir is determined, and finally an incremental inflow rate of fluid from the reservoir is calculated as being the difference between the total rate of fluid inflow less the original rate of gas flow. If the well is a gas well, the incremental fluid inflow is the actual gas inflow rate.

Abstract: An apparatus and process for obtaining representative samples of fluids produced from one or more oil wells by means of a closed vessel chamber with lease water supply port connected to a lease water supply line, where a pressure sensor within such internal chamber is used together with a flowmeter and liquid-sensing probe or oil/water interface sensor employed in the fluid flow path lines to determine a rate of well production along with absolute or relative amounts of oil, water and gas contents.

Abstract: An improved method of fluid analysis in the borehole of a well. A fluid sampling tool is fitted with a pumpout module that can be used to draw fluids from the formation, circulate them through the instrument, and then expel this fluid to the borehole. It has been determined that certain measurements would be most valuable to implement down hole, such as the formation fluid bubble point and dew point. Accurate bubble point and dew point measurements are made by forming bubbles or a liquid drop in a measured sample, and detecting same.