Abstract: A method of integrating a relay bank for use with a pool or spa control system includes, establishing an electrical connection between the relay bank and a control panel, discovering the relay bank by a control panel processor, and assigning the relay bank a network address upon discovery thereof. A method of integrating a smart component for use with a pool or spa control system includes, establishing an electrical connection between the smart component and a control panel, discovering the smart component by a control panel processor, and assigning the smart component a network address upon discovery thereof. A method of integrating an expansion panel for use with a pool or spa control system includes, establishing an electrical connection between the expansion panel and a control panel, discovering the expansion panel by a control panel processor, and configuring the expansion panel upon discovery thereof.

Abstract: A method for determining wettability of a solid, such as a reservoir rock material includes disaggregating the material, for example by grinding and placing the disaggregated material on the surface of the fluid. The wettability is analyzed based on whether a portion of the material floats on or sinks into the fluid. The method is well suited for heterogeneous solid materials that have mixed wetting characteristics and/or have varying surface types. The fluid can be evaluated as a potential treatment fluid or a component thereof that can be used for treating the rock formation. For example, the potential treatment fluid can include a surfactant or an oxidizing agent. A simple observation can be made whether substantially all of the material placed on the surface of the fluid sinks into the fluid, or the portions of floating and sinking material can be weighed.

Abstract: Systems and methods for analyzing produced fluids in a mature water flood (or EOR scheme) and determining whether the introduction of an EOR agent, such as a chemical or a gas additive, or some other alteration in treatment, is enhancing the recovery of hydrocarbon from parts of the reservoir otherwise untouched by injected fluids. The monitoring can be used to identify subtle changes in the produced fluid caused by their flow through different pore structures. In a carbonate formation for example, ions and salts from the rock fabric are dissolved into the reservoir fluids, whether they are water or oil. These can be detected by various fluid analysis and particularly water analysis methods. The changes in reservoir fluid paths associated with the injection of an EOR agent are detected in the observation well.

Abstract: A method for determining a characteristic of an underground formation with a fluid is described. The method includes providing a sample material of the underground formation; measuring the permeability and the porosity of the sample material; performing a drainage test on the sample material using the fluid; estimating the threshold pressure of the sample material from the drainage test, the permeability and the porosity measurements; and determining the receding contact angle of the fluid on the sample material from the threshold pressure. The sample material can be disaggregated material.

Abstract: A hydrocarbon-bearing subterranean formation may be treated with an aqueous well treatment fluid which contains a hexose oxidase, such as glucose oxidase, mannose oxidase or galactose oxidase. The aqueous well treatment fluid further may contain a viscosifying polymer and an aldohexose. The aldohexose reacts in-situ with the hexose oxidase and molecular oxygen to produce hydrogen peroxide. The hydrogen peroxide may then act as a breaker.

Abstract: Methods, apparatuses and computer readable instructions for determining the effectiveness of, and for performing, a low salinity waterflood. An ion diffusion distance value is determined based on the rate of diffusion of ions within the rock of a reservoir and the residency time of floodwater within the reservoir. The thickness of the layers of the reservoir are compared to this ion diffusion value to determine the effectiveness of performing a low salinity waterflood and also to enable the effective control of a waterflood and to assist in the determination of locations of wells.

Abstract: A method of controlling fluid flow into a heavy oil production pipe includes reducing inflow into the production pipe locally from hot spots using inflow control devices including a movable body provided within a housing, the movable body being arranged to adjust the flow of fluid through the inflow control devices autonomously by exploiting the Bernoulli principle; increasing inflow into the production pipe remote from the hot spots using the inflow control devices to increase inflow locally; and increasing draw down in the production pipe by using an injector to inject a gaseous medium at or downstream of the inflow control devices.

Abstract: A system and method for optimizing sweep efficiency of an enhanced oil recovery process in a subterranean reservoir is disclosed. The system and method include computing a displacement coefficient representative of heterogeneity of an unswept region in the subterranean. A functional relationship between operating conditions of one or more well control devices and the displacement coefficient is determined. The sweep efficiency of the enhanced oil recovery process can be optimized by adjusting the well control devices such that the displacement coefficient is minimized. Streamline simulation can be utilized to compute the displacement coefficient from the flow capacity and storage capacity of the unswept region in the subterranean reservoir.

Abstract: Systems and methods are described for analyzing produced fluids in a mature water flood (or EOR scheme) and determining whether the introduction of an EOR agent, such as a chemical or a gas additive, or some other alteration in treatment, is enhancing the recovery of hydrocarbon from parts of the reservoir otherwise untouched by injected fluids. The monitoring can be used to identify subtle changes in the produced fluid caused by their flow through different pore structures. In a carbonate formation for example, ions and salts from the rock fabric are dissolved into the reservoir fluids, whether they are water or oil. These can be detected by various fluid analysis and particularly water analysis methods. The changes in reservoir fluid paths associated with the injection of an EOR agent are detected in the observation well.

Abstract: A hydrocarbon-bearing subterranean formation may be treated with an aqueous well treatment fluid which contains a hexose oxidase, such as glucose oxidase, mannose oxidase or galactose oxidase. The aqueous well treatment fluid further may contain a viscosifying polymer and an aldohexose. The aldohexose reacts in-situ with the hexose oxidase and molecular oxygen to produce hydrogen peroxide. The hydrogen peroxide may then act as a breaker.

Abstract: Prior to a hydraulic fracturing treatment, the requisite apparent viscosity of a transport fluid, ?fluid, containing a proppant for a desired propped fracture length of a fracture, DPST, may be estimated in accordance with Equation (I): ?fluid=(1/A)×qi×(1/DPST)B×(CTRANS)×(?SGPS)×(d2prop)??(I) wherein: A is the multiplier and B is the exponent from the Power Law equation of velocity of the transport slurry vs. distance for the fracture geometry; qi is the injection rate per foot of injection height, bpm/ft; CTRANS is the transport coefficient; ?SGPS is SGprop?SGfluid, SGprop being the specific gravity of the proppant and SGfluid being the specific gravity of the transport fluid; and dprop is the median proppant diameter, in mm.

Abstract: An apparatus and method are disclosed for sensing a characteristic of a borehole. An exemplary apparatus includes a conductive pipe; an inlet, connected to the conductive pipe, for applying pulse to the conductive pipe; a resonant network device connected with the conductive pipe; and a transducer which is in operative communication with the resonant network device to measure a borehole characteristic, the transducer being configured to sense a modulated vibration frequency induced in the resonant network device when a pulse is applied to the inlet.

Abstract: A method of reducing the viscosity of a water-based drilling fluid without requiring dilution. The method of reducing the viscosity of a water-based drilling fluid, includes: providing a water-based drilling fluid containing a peroxide degradable polymer and a weighting agent, adding a viscosity reducing additive containing an inorganic peroxide to the water-based drilling fluid while maintaining the pH of the water-based drilling fluid at a pH greater than about 8, circulating the water-based drilling fluid having a pH greater than about 8 through a wellbore, and heating the circulating water-based drilling fluid to a temperature of at least about 150° F. so as to activate the inorganic peroxide to degrade the peroxide degradable polymer.

Abstract: In-situ formation fluid evaluation methods and apparatus configured to measure a first resonance frequency of a first fluid using a first densimeter downhole, wherein a first density of the first fluid is known; measure a second resonance frequency of a second fluid using a second densimeter downhole, wherein the second fluid is a formation fluid received by the second densimeter downhole, and wherein a second density of the second fluid is unknown; and determine the second density of the second fluid using the first and second resonance frequencies and the known first density.

Abstract: Two new flow parameters derived from laboratory core-flood experiments are used in building mathematical models to predict the performance of an acid treatment when treatment is made with self diverting fracturing acids. The two new variables are: ?Pr is defined as the value of ?p (in the core flood experiment) when ?p switches from a first to a second linear trend at time tr ?r is the number of pore volumes injected when the switch occurs.

Abstract: Circulating completion, workover and drilling fluids used in hydrocarbon recovery are filtered after monitoring for viscosity, which frequently causes plugging of filters. A viscometer generates a signal representative of viscosity in the fluid; the signal is used by a programmable controller to divert viscous fluid from the filter, or to take other action to prevent damage to the filter. The viscometer can be used in various positions in the system. Fluids deemed too viscous for the filter can be sent to a viscosity-reducing device, which may be a heating, shear-thinning, or cavitation device, to reduce its viscosity, enabling the fluid to pass through a filter without fouling. After filtering and a return to a lower temperature, the fluid may be treated if necessary to become viscous again for a useful purpose.

Abstract: A device determines the specific gravity of a wellbore fluid flowing into a submersible pump. The specific gravity of the wellbore fluid is determined by measuring the pressure increase across at least two pump stages and then using fluid flow properties and known pump characteristics to back calculate the specific gravity of the wellbore fluid.

Abstract: A method of sampling fluid from a rock formation penetrated by a borehole includes positioning a downhole tool having a flow line in the borehole, establishing an inlet port through which fluid passes from a first point in the formation into the flow line, establishing an outlet port through which fluid passes from the flow line into a second point in the formation, and passing fluid between the formation and the flow line through the inlet and outlet ports.

Abstract: The invention provides a method of treating a subterranean formation penetrated by at least one injection well and at least one production well, the method comprising the steps of a) analyzing the injection well, the production well, and reservoir contained in the subterranean formation; b) selecting at least one fluid and at least one permeability reducer to be placed in flow ways contained within the formation; and c) performing a formation permeability modification using the selected fluids and at least one permeability reducer, whereby the flow of injected driving fluid between the injection well and production well is substantially reduced. In one embodiment, the method of analyzing the injection well, the production well, and reservoir contained in the subterranean formation includes the steps of evaluation of completion information, reservoir data, or both.

Abstract: 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.

Abstract: A system and method to model and analyze the mixing energies of high-yielding non-Newtonian fluids to prevent chemical lost circulation. Laboratory tests are performed under varying conditions from which data on the mixing energies needed to optimize the use of high-yielding non-Newtonian fluids to prevent lost circulation is obtained. This data is then applied to a non-linear mathematical modeling system that is capable of scaling the data to give a dimensionless value. This value can be combined with historic information to predict optimal flow rates and mixtures to prevent chemical lost circulation. This data may be verified by means of simulation, lab testing, or application to a full-size well.

Abstract: The invention provides a method of treating a subterranean formation penetrated by at least one injection well and at least one production well, the method comprising the steps of a) analyzing the injection well, the production well, and reservoir contained in the subterranean formation; b) selecting at least one fluid and at least one permeability reducer to be placed in flow ways contained within the formation; and c) performing a formation permeability modification using the selected fluids and at least one permeability reducer, whereby the flow of injected driving fluid between the injection well and production well is substantially reduced. In one embodiment, the method of analyzing the injection well, the production well, and reservoir contained in the subterranean formation includes the steps of evaluation of completion information, reservoir data, or both.

Abstract: Earth formations are characterized by using an array of electrodes which can measure streaming potentials in the formation, and by interpreting the data obtained by the electrodes. The electrodes are placed on a wireline tool, a LWD tool, or in a fixed manner about a completed wellbore. The measured streaming potentials are generated by drilling with an overbearing pressure, slitting the mudcake in a borehole, acid injection, or any of various other manners which causes fluid movement. The data obtained is interpreted to locate fractures, measure formation permeability, estimate formation pressure, monitor drilling fluid loss, detect abnormal pressure, etc. Particularly, a streaming potential voltage transient having a double peak profile signifies the presence of a formation fracture.

Abstract: A method for selectively reducing the permeability of one or more relatively permeable geological layers of an oil-bearing formation, to inhibit breakthrough of driving fluid from a driving fluid injection well via at least one of said layers into an oil production well, which method comprises the steps of injecting a driving fluid comprising a first compound into the formation via the injection well; detecting the first compound in well fluid of the oil production well; upon detection, injecting a second compound into the formation via the oil production well, to react with the first compound in order to provide a flow restriction generated by a third compound which comprises a reaction product of the first and second compounds in at least one relatively permeable geological layer through which breakthrough of the driving fluid into the oil production well has occurred.

Abstract: Circulating completion and workover fluids used in hydrocarbon recovery are filtered after monitoring for viscosity, which frequently causes plugging of filters. A viscometer generates a signal representative of viscosity in the fluid; the signal is used by a programmable controller to divert viscous fluid from the filter, or to take other action to prevent damage to the filter. The viscometer can be used in various positions in the system.

Abstract: A viscometer for a down hole tool positionable in a well bore penetrating a subterranean formation is described. The formation contains at least one fluid therein. The down hole tool is adapted to convey at least a portion of the fluid to the viscometer. The viscometer comprises a sensor unit, and at least one magnet. The sensor unit is positionable within the down hole tool and comprises at least two spatially disposed clamps and a wire suspended in tension between the at least two clamps such that the wire is available for interaction with the fluid when the viscometer is positioned within the down hole tool and the down hole tool is positioned within the subterranean formation and receives the fluid from the subterranean formation.

Abstract: Formation testing, resistivity and NMR measurements are used concurrently to determine a relative permeability representative of a formation surrounding the borehole. A method and apparatus is provided for accurate determination of the relative permeability for a formation by measuring saturation levels in a region of interest determined from resistivity or NMR readings versus time during formation draw down pressure testing. The method and apparatus determines and effective permeability over time for various saturation levels to determine the relative permeability for the formation at each saturation level and also enables determination of the efficacy of utilizing completion fluids in the formation to increase formation productivity. The method and apparatus enables more accurate determination of effective permeability and the irreducible saturation level.

Abstract: In a method for drilling, completing and fracturing a subterranean formation, an electrical potential is applied to oil or synthetic based drilling fluid to increase the viscosity of the fluid and enable the fluid to entrain drill cuttings and proppant. The same base fluid may be used for drilling, completion and fracturing by adjusting the electrical potential and consequently the viscosity of the fluid for the particular application. In fracturing, little or no potential is applied until the fluid enters the zone of the formation to be fractured. High potential is then applied at the fracture point of the formation to effect fracturing and to enable the fluid to transport proppant into the fracture.

Abstract: Methods for determining formation characteristics comprising establishing baseline casing conditions for a string of casing disposed within a wellbore in a formation and measuring updated casing conditions for the string of casing at a first time interval from the establishing of the baseline casing conditions. The baseline casing conditions are compared to the updated casing conditions to determine changes in the string of casing over the first time interval. These changes in the string of casing are then used to determine formation characteristics.

Abstract: Determining the in situ effective mobility of a formation layer comprises selecting a location in the formation layer; lowering in the borehole traversing the formation layer a tool that comprises a central conduit having an inlet and being provided with a pressure sensor, a fluid receptacle having an inlet opening into the central conduit. a fluid analyser, and means for discharging fluid; making an exclusive fluid communication between the formation and the inlet of the central conduit; allowing formation fluid to pass through the central conduit, analysing the fluid, allowing the formation fluid to enter into the fluid receptacle when the fluid is the substantially uncontaminated formation fluid, and measuring the pressure build-up: and determining the effective mobility from the pressure build-up.

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 method is described for using an electro-rheological fluid as a drilling and completion fluid or as a well service or fracturing fluid. By adjusting the viscosity of the fluid through application of an electrical potential to the fluid, the fluid has enhanced flexibility and multiplicity of purpose over prior art fluids.

Abstract: A method of performing a formation rate analysis from pressure and formation flow rate data. Pressure and flow rate data are measured as fluid is withdrawn from a formation. Variable system volume is accounted for. The pressure and flow rate data are correlated using a multiple linear regression technique. Time derivative terms related to pressure and flow rate are smoothed using a summation technique, thereby providing better correlations than using the time derivatives directly. Formation parameters comprising formation permeability, formation pressure, and fluid compressibility may be determined from the correlation.

Abstract: A method of performing a formation rate analysis from pressure and formation flow rate data. Pressure and flow rate data are measured as fluid is withdrawn from a formation. Variable system volume is accounted for. The pressure and flow rate data are correlated using a multiple linear regression technique. Time derivative terms related to pressure and flow rate are smoothed using a summation technique, thereby providing better correlations than using the time derivatives directly. Formation parameters comprising formation permeability, formation pressure, and fluid compressibility may be determined from the correlation.

Abstract: A method is described for using an electro-rheological fluid as a drilling and completion fluid or as a well service or fracturing fluid. By adjusting the viscosity of the fluid through application of an electrical potential to the fluid, the fluid has enhanced flexibility and multiplicity of purpose over prior art fluids.

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 determining permeability of a subterranean formation is provided. The apparatus and method comprise a work string, at least one selectively extendable member mounted on the work string to isolate a portion of the annular space between the work string and borehole. A predetermined distance proportional to the radius of a control port separates at least two ports in the work string. A sensor operatively associated with each port is mounted in the work string for measuring at least one characteristic such as pressure of the fluid in the isolated section.

Abstract: A novel method, system and tool for performing formation and well evaluation while drilling are disclosed. These inventions determine the properties of a particular formation within a reservoir as the reservoir is being intersected during well construction. In one form of the invention, the formation evaluation is made using a direct measurement of the formation's ability to flow fluids. The flow potential of a reservoir during underbalanced well construction is determined as the well is being constructed. The methods produce an understanding of the volumes and types of fluids such as oil, gas, and/or water, that can be produced out of discrete sections of a formation within a reservoir as the reservoir is intersected.

Abstract: A method and apparatus for performing sand control using fracturing is described. A curve is defined that correlates the percentage of flow through out-of-phase perforations (those perforations not aligned with fractures) with the fracture conductivity over formation permeability. Given a desired production flow, formation conductivity may be defined. This allows the well operator to perform the proper fracturing operation to achieve the desired fracture conductivity. Alternatively, after a well has been fractured, and sand production is observed, a critical flow rate and the corresponding drawdown pressure can be calculated to prevent sand production.

Abstract: Characterization of organic contaminants in subsurface formation is performed by methods for detecting the presence of nonaqueous phase liquid in a subsurface formation, and for determining the composition and for determining the volume of nonaqueous phase liquids. Generally the methods comprise introducing one or more partitioning tracers and one or more non-partitioning tracers at one or more injection points located in the subsurface formation and measuring separation between the one or more partitioning tracers and the one or more non-partitioning tracers from one or more sampling points located in the subsurface formation to determine presence, composition and/or volume of nonaqueous phase liquid in the subsurface formation. In addition, the methods can be used to assess the performance of an attempted remediation.