Abstract: The disclosed embodiments include methods to perform an in-situ determination of a formation property of a downhole formation, methods to operate a tool to perform an in-situ determination of formation properties of a downhole formation, and in-situ formation property measurement tools. In one embodiment, a method to perform an in-situ determination of a formation property includes deploying a tool into a borehole that is drilled through a formation. The method also includes isolating a source zone from an injection zone. While the source zone is isolated from the injection zone, the method further includes withdrawing a fluid that partially fills the source zone; flowing the fluid into the injection zone; injecting the fluid into a first portion of the formation that is along the injection zone; and determining at least one formation property of the first portion based on an injection of the fluid into the first portion.

Abstract: The present invention discloses a numerical simulation method for proppant transport considering wall-retardation effect, comprising the followings: establish a physical model of laboratory experiment on proppant transport with a large flat-panel device; establish a drag coefficient model considering wall-retardation effect according to the numerical simulation experiment; establish a computational geometric model; set boundary conditions and physical parameters of the geometric model according to the two-fluid simulation method for solid proppant quasi-fluidization; verify the grid independence of the computational geometric model to obtain the transport characteristics and placement pattern of the proppant in fractures. The present invention employs a numerical simulation method to study the migration and distribution patterns of proppant under the retardation effect of narrow walls during the hydraulic fracturing.

Abstract: Disclosed are systems and methods for receiving, by at least one processor, a first indication to transition from a powered-off state to a low power standby state, in response to the first indication, obtaining, by the at least one processor, from at least one sensor at least one sensor measurement comprising data corresponding to a downhole environment, determining, by the at least one processor, that the at least one sensor measurement exceeds a particular threshold comprising a second indication and transitioning from the low power standby state to a logging state, in response to the second indication, capturing, by the at least one processor, the data corresponding to the downhole environment, and storing, by the at least one processor, the data corresponding to the downhole environment.

Abstract: A tool assembly and method are for performing formation stress testing in an openhole section of a borehole, wherein the openhole section of the borehole is to be provided with, or already have been provided with, a perforation tunnel generated by a series of electrically induced focused acoustic shock waves. The tool assembly has at least two borehole isolation means arranged with an axial distance therebetween for forming an isolated section at the openhole section of the borehole; a pump device for altering a pressure within the isolated section; a pressure sensor for measuring a pressure within the isolated section; a control unit for controlling a testing sequence; an acoustic shock wave device for generating the series of acoustic shock waves to excavate the perforation tunnel; and an acoustic shock wave sub for actuating the acoustic shock wave device.

Abstract: Example embodiments are described for a method and system for logging data processing in determining permeability anisotropy effects. A permeability anisotropy model is used to derive a relationship between formation permeability anisotropy and resistivity anisotropy in both TI and BA formations. Implementations can provide the permeability anisotropy plus the true reservoir (or sand) permeability by using an integrated interpretation of the MCI resistivity anisotropy measurements with conventional permeability logs from other sensors (e.g., NMR or sonic). Biaxial and triaxial permeability components of the permeability anisotropy tensor can be determined for application to synthetic and field log interpretations.

Abstract: The embodiments of the present disclosure disclose a method and an apparatus for determining the permeability of the reservoir. The method comprises: acquiring logging data corresponding to the two zones at least; determining the permeability of a specified zone in the two zones at least based on logging data corresponding to the specified zone, wherein the specified zone represents any one of the two zones at least; setting weight values corresponding to the at least two zones respectively; and determining the permeability of the reservoir based on the weight values and the permeability respectively corresponding to the two zones at least. The technical solutions provided by the embodiments of the present disclosure can improve the accuracy of the determined permeability of the reservoir.

Abstract: A hydrocarbon reservoir model simulation is executed to distribute gas among available gas injectors associated with a hydrocarbon reservoir. Using the result of the executed hydrocarbon reservoir simulation, streamline tracing is executed to calculate hydrocarbon flow fields. Using the results of the executed hydrocarbon reservoir simulation and the executed streamline tracing, a reservoir pressure equalization (RPE) algorithm is executed to distribute an amount of gas according to an injection strategy to satisfy an assigned voidage replace ratio (VRR) for each region of the hydrocarbon reservoir. Post-processing of the results of the RPE algorithm is performed. Using the result of the post-processing, gas injection in the hydrocarbon reservoir is performed with the available gas injectors.

Abstract: This disclosure relates to a sensor for imaging boreholes with improved durability to impact along the wall of the borehole, which may protect the sensor from premature wear. Such an apparatus may include a housing, one or more button electrodes coupled to the housing, one or more current return electrodes couple to the housing, and a guard electrode disposed at least partly around the one or more button electrodes. The one or more button electrodes may transmit or receive an electrical or electromagnetic signal through the underground formation, and the one or more current return electrodes receive or transmit the signal. The guard electrode may block portions of the electrical or electromagnetic signal that did not pass through the underground formation. In addition, the guard electrode may include a number of holes to enable the guard electrode to couple to the housing while providing additional structural durability.

Abstract: One aspect includes a method for use with a plurality of steam assisted gravity drainage wells. The method includes designing a first modeling framework which provides a model of total output for the plurality of wells from one or more input variables for respective ones of the plurality of wells. The method also includes designing a second modeling framework which provides a model of output for a given one of the plurality of wells based at least in part on one or more input variables for the given one of the plurality of wells and one or more input variables for at least another one of the plurality of wells. The method further includes utilizing the first and second modeling frameworks to determine an optimal configuration for the wells and configuring the well to operate with the determined optimal configuration.

Abstract: One aspect includes a method for use with a steam assisted gravity drainage well. The method includes generating an analytical framework for the well at least in part by modeling one or more observable variables as a function at least of one or more control variables; and modeling one or more output variables as a function at least of at least one of the one or more control variables; and at least one of the one or more observable variables. The method further includes utilizing the analytical framework to determine an optimal configuration for the well, the optimal configuration including a set of one or more values for the one or more control variables which produce one or more desired values for the one or more output variables; and configuring the well to operate with the determined optimal configuration.

Abstract: Methods are provided for determining saturation parameters of a formation while sampling the formation. Flow rate and pressure data may be used in order to provide mobility information close to the probe. In turn, the mobility information may be used in conjunction with at least water fraction information in order to provide an estimation of saturation parameters of the formation such as maximum residual oil saturation Sorm, connate water saturation Swc, and residual water saturation Swr. Resistivity measurements may be used to help in the estimation of the saturation parameters. Initial estimations may be used as the starting parameters for a full parameter inversion. An interpretation scheme in the absence of invasion details is provided.

Abstract: Methods are disclosed for processing, in real-time, pressure data acquired with a formation tester during a pretest to quickly establish the quality of the measurement being conducted. The methods can optimize pressure measurement operations by assessing whether it is desirable or not to wait for the formation tester flowline pressure to equilibrate to the sandface pressure. In one embodiment, a determination is made as to whether the pretest succeeded in establishing hydraulic communication between the formation and the flowline by comparing the pressure signal with a simulation of the pressure behavior corresponding to a false buildup during a dry test. In another embodiment, a determination is made as to whether the pretest succeeded in isolating the tool flowline and the formation from the wellbore by using the pressure signal to estimate the sandface pressure during buildup over time, and to compare the estimated sandface pressure signal with the borehole pressure.

Abstract: A system and method utilizing one or more perforation filters to determine the location of perforation intervals along a well trace within a reservoir model. The filters may define the location of the perforation intervals based upon, for example, rock property, facies, fluid boundary, geobody, or dynamic fluid property.

Abstract: Systems, methods, and media for modeling and filtering noise in seismic surveys are disclosed. Methods, systems, and computer program products in accordance with the present disclosure perform operations including obtaining seismic information of a region resulting from a source waveform applied to the region. The operations also include obtaining an estimate of visco-elastic properties of a near-surface of the region. The operations further include determining an estimate of propagation of guided waves in the region based on the estimate of visco-elastic properties of a near-surface of the region. Additionally, the operations include determining a model of the guided waves in the near-surface of the region using the estimate of propagation of the guided waves and an estimate of the source waveform. Moreover the operations include determining a filtered output of the seismic information by removing the model of the guided waves from the seismic information.

Abstract: A method and an apparatus for characterizing a fluid provide for flowing a sample fluid through a microfluidic flow line in a first direction and into contact with a microfluidic sensor, measuring a property of the fluid sample using the microfluidic sensor; and after measuring the property of the fluid sample, flushing the microfluidic sensor by flowing a solvent through the microfluidic flow line in a second direction that is opposite the first direction.

Abstract: Methods for determining an optimal surfactant structure for oil recovery are described. These methods systematically evaluate surfactants' phase behavior at ambient and at reservoir conditions; cloud point from ambient to reservoir conditions; dynamic interfacial tension at ambient and at reservoir conditions, including crude oil bubble images and fitting drop profiles; static contact angles at ambient conditions and dynamic contact angles at reservoir conditions; spontaneous imbibition at ambient conditions; and forced imbibition at reservoir conditions.

Abstract: Systems, methods and devices for dielectric borehole imagery are disclosed. Systems may include one or more transmitters that induce, at azimuthally-spaced positions on a borehole wall, a plurality of fields having components in non-coplanar directions within a formation; one or more directionally sensitive receivers that sense the components caused by each of the one or more transmitters; and a controller that processes signals received from the one or more directionally sensitive inductive sensors to provide a set of measurements representative of dielectric parameters at two or more azimuthal positions within the borehole.

Abstract: A method of treating a siliciclastic, hydrocarbon-bearing formation includes contacting the hydrocarbon-bearing formation with a composition comprising solvent and a fluorinated amine oxide. The method can provide siliciclastic, hydrocarbon-bearing formations treated according to the method.

Abstract: 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.

Abstract: An apparatus and a method for recovering hydrocarbons from a subterranean formation including collecting baseline and subsequent sonic data. Either open or cased hole Stoneley and cross dipole dispersions are calculated using the baseline and subsequent sonic data, the minimum and maximum horizontal stress magnitudes are calculated using the calculating dispersions, a pressure is calculated and hydrocarbons are recovered.

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: A method for pyrolyzing organic matter in a subterranean formation includes powering a first generation in situ resistive heating element within an aggregate electrically conductive zone at least partially in a first region of the subterranean formation by transmitting an electrical current between a first electrode pair in electrical contact with the first generation in situ resistive heating element to pyrolyze a second region of the subterranean formation, adjacent the first region, to expand the aggregate electrically conductive zone into the second region, wherein the expanding creates a second generation in situ resistive heating element within the second region and powering the second generation in situ resistive heating element by transmitting an electrical current between a second electrode pair in electrical contact with the second generation in situ resistive heating element to generate heat with the second generation in situ resistive heating element within the second region.

Abstract: Systems and methods for controlling in situ resistive heating elements may be utilized to enhance hydrocarbon production within a subterranean formation. An in situ resistive heating element may be controlled by heating a controlled region associated with the in situ resistive heating element, injecting a control gas into the controlled region, and adjusting the electrical conductivity of the controlled region with the control gas. The controlled region may be located such that the heating and injecting may change the shape of the in situ resistive heating element and/or guide the in situ resistive heating element towards subterranean regions of potentially higher productivity and/or of higher organic matter.

Abstract: A method for determining along relatively uniformly spaced apart parallel first and second wellbores situated in an underground hydrocarbon-containing formation, regions within the formation, including in particular regions between such wellbores, where injection of a fluid at a pressure above formation dilation pressure may be advantageous in stimulating production of oil into the second of the two wellbores, and subsequently injecting fluid at pressures above formation dilation pressures at the discrete regions along such wellbores determined to be in need. An initial information-gathering procedure is conducted, wherein fluid is supplied under a pressure less than formation dilation or fracture pressure, to discrete intervals along a first wellbore, and sensors in the second wellbore measure and data is recorded regarding the ease of penetration of such fluid into the various regions of the formation intermediate the two wellbores.

Abstract: A method for determining along a length of a wellbore situated in an underground hydrocarbon-containing formation, regions within the formation where injection of a fluid at a pressure above formation dilation pressure may be advantageous in stimulating production of oil into the wellbore. An initial information-gathering procedure is conducted prior to formation dilation/fracturing, wherein fluid is supplied under a pressure less than formation dilation or fracture pressure, to discrete intervals along the wellbore, and sensors measure and data is recorded regarding the ease of penetration of such fluid into the various regions of the formation. Regions of the formation exhibiting poor ease of fluid penetration or regions of higher oil saturation, are thereafter selected for subsequent stimulation or dilation, at pressures above formation dilation pressures. Where initial fluid pressures and/or formation dilation pressures are provided in cyclic pulses, as novel downhole tool is disclosed for such purpose.

Abstract: A method of performing a stimulation operation at a wellsite is provided. The wellsite has a wellbore penetrating a formation having fractures therein. The method involves predicting placement of proppant parameters in the fractures based on wellsite data, generating an asperity model based on the predicted placement, predicting aperture change for a prescribed closure stress using the asperity model, and determining fracture conductivity based on the predicted aperture change. The method also involves placing into the fractures with a stimulation fluid by injecting the stimulation fluid having the proppant therein into the formation based on the determined fracture conductivity and producing fluid from the reservoirs and into the wellbore through the propped fractures.

Abstract: A downhole formation fluid pumping and a sampling apparatus are disclosed that may form part of a formation evaluation while drilling tool or part of a tool pipe string. The operation of the pump is optimized based upon parameters generated from formation pressure test data as well as tool system data thereby ensuring optimum performance of the pump at higher speeds and with greater dependability. New pump designs for fluid sampling apparatuses for use in MWD systems are also disclosed.

Abstract: Embodiments herein relate to a method for recovering hydrocarbons from a formation including collecting and analyzing a formation sample, drilling operation data, and wellbore pressure measurement, estimating a reservoir and completion quality, and performing an oil field service in a region of the formation comprising the quality. In some embodiments, the formation sample is a solid collected from the drilling operation or includes cuttings or a core sample.

Abstract: Systems and methods for accessing and/or harvesting hydrocarbons from a wellbore. A method may include modeling a well to determine a length of a stimulation zone in the production interval, wherein the model is based, at least in part, on a reaction time for a stimulation process. Packers are placed in the well to fluidically isolate the stimulation zone from other zones in the well. The targeted zone is stimulated, such as by acid treatment. Hydrocarbons may be recovered from the stimulation zone.

Abstract: A method of analyzing a wellbore fluid that includes treating a wellbore fluid with an emulsifying fluid, the emulsifying fluid comprising: a hydroxylated ether; an amphoteric chemotrope; and testing the treated wellbore fluid for at least one of turbidity and total suspended solids is disclosed. Methods of cleaning wellbores are also disclosed.

Abstract: Methods and systems for in-situ characterization of a reservoir rock are provided. One method includes: (a) sealing an interval corresponding to a selected depth or depths within the subterranean formation; (b) injecting a displacement fluid into the interval, wherein the displacement fluid displaces a reservoir fluid stored in the reservoir rock; (c) monitoring movement of the displacement fluid or the reservoir fluid in the reservoir rock; and (d) assessing wettability of the reservoir rock based on (c) or determining recovery rate of the reservoir fluid.

Abstract: 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.

Abstract: A method for determining pore-space metrics for geological samples may include receiving an image of a geological sample, determining, via image processing, pore-space regions within the image of the geological sample, and measuring the pore-space regions to provide a pore-space metric for the geological sample. The method may also include determining a geo-mechanical property for the geological sample using the pore-space metric and adjusting a hydrocarbon recovery operation according to the pore-space metric or the geo-mechanical property. A corresponding system and apparatus are also disclosed herein.

Abstract: A method for evaluating wellbore integrity including introducing a drill to a surface of a casing encompassing an annulus, enclosing the drill in a housing hydraulically isolating the surface, drilling through the casing and into cement surrounding the casing, observing a pressure of the fluid, and using the pressure observation and a drill position to evaluate a presence of a defect and a location of the defect. Apparatus for evaluating wellbore integrity including a probe comprising a drill, wherein the probe is hydraulically isolated from the wellbore, a valve that encompasses the drill, a pressure gauge to measure the pressure of the fluid within the housing, a pressure gauge to measure the pressure in the system outside the housing, and equipment to compare the pressure measurements and the position of the drill and to evaluate a presence and a location of the defect.

Abstract: The present invention is directed toward a method and an apparatus to investigate and quantify a leakage rate for a fluid 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 defined by the first pipe and the second pipe, where fluid in the gaseous phase is conveyed through the measuring arrangement, as the annulus is used as a separation chamber for gas and liquid.

Abstract: A method is described for recovery of a hydrocarbon fluid from a porous medium by injection of a fluid into the porous medium. The method includes determining a Rayleigh time on the basis of the density of the fluid and the hydrocarbon fluid, the median pore diameter of the porous medium, and surface tension between the fluid and the hydrocarbon fluid. Further, pressure stimulation is provided in the fluid and generated by a collision process with a collision contact rise time which is of the range of 1-100 times the Rayleigh time. Alternatively or additionally, the providing a pressure stimulation in the fluid include generating an impact pressure with a pressure amplitude I and a pressure rise time ?t, where the pressure amplitude is larger than the relation ?c?t/a2, where ? is the surface tension between the fluid and the hydrocarbon fluid, and c is the speed of sound in the porous media.

Abstract: A bottomhole assembly is provided with a cathode. The cathode produces a static field in the earth formation and by the electroosmotic effect, inhibits the invasion of the formation by borehole fluids and reduces formation damage. The cathode also results in improved estimates of formation permeability using flow tests. A cathode on a wireline string may be used to reduce water saturation in an invaded zone near a borehole.

Abstract: A downhole tool is conveyed within a wellbore extending into a subterranean formation, and then utilized to obtain measurements at multiple different depths of investigation within the subterranean formation relative to the wellbore. The obtained measurements are then compared to assess mobility of oil within the subterranean formation.

Abstract: A method of performing a stimulation operation for a subterranean formation penetrated by a wellbore is provided. The method involves collecting pressure measurements of an isolated interval of the wellbore during injection of an injection fluid therein, generating a fracture closure from the pressure measurements, generating transmissibility based on the fracture closure and a mini fall off test of the isolated interval during the injection, obtaining fracture geometry from images of the subterranean formation about the isolated interval, and generating system permeability from the transmissibility and the fracture geometry. The method may also involve deploying a wireline stimulation tool into the wellbore, isolating an interval of the wellbore and injecting fluid into the interval with the wireline stimulation tool. The fracture geometry may be obtained by imaging the formation, and fracture geometry may be obtained from core sampling.

Abstract: A system performs methods for well and reservoir management for optimized production of fluids in a reservoir. The system includes a knowledge engine configured to receive a plurality of field inputs, process and analyze the field inputs, and provide a plurality of outputs for presentation to an operator. The system also includes a user data interface configured to display the plurality of data outputs. The plurality of field inputs comprises chemical sensing data and at least one of: temperature, pressure, flow rate and concentration of production components from one or more individual wells located within the reservoir, seismic surveys of the reservoir, permeability, geochemistry and lithology of rock formations, and geographic information system (GIS) data associated with the reservoir.

Abstract: A method of flow testing multiple zones in a wellbore includes lowering a tool string into the wellbore. The tool string includes an inflatable packer or plug and an electric pump. The method further includes operating the pump, thereby inflating the packer or plug and isolating a first zone from one or more other zones; monitoring flow from the first zone; deflating the packer or plug; moving the tool string in the wellbore; and operating the pump, thereby inflating the packer or plug and isolating a second zone from one or more other zones; and monitoring flow from the second zone. The zones are monitored in one trip.

Abstract: Method is directed to determining a fluid influx profile and near-wellbore area parameters in multi-layered reservoirs. A bottomhole pressure in a wellbore is measured. After operation of the wellbore at a constant production rate, the production rate is changed. A bottomhole pressure is measured together with a fluid influx temperature for each productive layer. Graphs of the fluid influx temperature measured as a function of time and of a derivative of this temperature with respect to a logarithm of a time passed after the production rate is changed as a function of time are plotted. Relative production rates and skin factors of the productive layers are calculated based on these graphs.

Abstract: A method and apparatus for determining the fluid permeability of an earth formation is described. An instrument comprising an acoustic source and acoustic and electrokinetic sensors is located in a borehole at a site of interest. The acoustic source is fired and the resulting variations in pressure and electric field generated are measured and recorded. The Biot equation, and an equation for the streaming potential coupled to fluid displacement terms, is solved using finite element analysis to give an expected pressure waveform and electrokinetic waveform based on estimated earth formation properties. By comparison of the measured waveforms and those calculated from the equations, the actual permeability of the earth formation can be deduced.

Abstract: Method for determination of a fluid influx profile and near-wellbore area parameters comprises measuring a first bottomhole pressure and after operating a well at a constant production rate changing the production rate and measuring a second bottomhole pressure. A wellbore fluid temperature over an upper boundary of a lowest productive layer and wellbore fluid temperatures above and below other productive layers are measured and relative production rates and skin factors of the productive layers are calculated from measured wellbore fluid temperatures and measured first and second bottomhole pressures.

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: A method of evaluating a geological formation (20) of non-homogeneous porosity and permeability, particularly in exploration for hydrocarbon fluids, comprising the steps of: (a) inserting a formation evaluation tool (30) into a borehole (10) to a location (10a) within the geological formation (20); (b) setting the formation evaluation tool (30) into position isolating interval(s) of the borehole (10) with a packer arrangement (50) forming portion of the formation evaluation tool (30), for sample evaluation for said interval(s); (c) extracting representative samples of formation fluid from the location within the geological formation (20) for evaluation under downhole conditions using sampling means (32a, 52b, 54b) operative to extract formation fluid samples over a range of porosity and permeability encountered within the geological formation (20); and (d) analysing the formation fluid samples and measuring formation (20) permeability.

Abstract: A method for determining effects of perforation on a rock formation includes obtaining a sample of the rock formation. A perforation tunnel is created in the sample of the rock formation. The core sample is either subdivided into subsamples and a three dimensional tomographic image is made of each subsample and/or a three dimensional tomographic image is made of the sample of rock formation and the image thereof is segmented into sub images of selected subvolumes of the rock formation sample. At least one physical property of the rock formation is estimated from each tomographic image.

Abstract: A well passing through a geological formation is fitted with a tube, open at its bottom end, that is filled with a fluid. Another fluid is in the annular space between the tube and the wall of the well, the two fluids exhibiting an interface situated in the annular space. A hydraulic balance of the fluids of the well is disturbed and the trend of certain quantities is measured. These measurements are moreover simulated by computer by using different sets of values for the physical parameters, and efforts are made to estimate the geological formation. A comparison of the measurements with the simulation results makes it possible to identify an optimum set of values for the parameters.

Abstract: A method of constructing a well log of a quantitative property representative of a porous formation, from sample measurements and log data, is disclosed. A quantitative property (mineralogical proportions) of samples selected from among a set of samples is measured and each sample is grouped into homogeneous classes regarding the log data. The average value of the quantitative property is then determined in each class. A well log representing the probability of assigning a sample to each class as a function of depth is constructed. Finally, the well log representing the quantitative property as a function of depth is constructed from the log representing the assignment probability and from the average values.

Abstract: A treatment fluid for a well includes: (a) a water-soluble polymer, wherein the water-soluble polymer comprises a polymer of at least one non-acidic ethylenically unsaturated polar monomer; (b) an organic crosslinker comprising amine groups, wherein the organic crosslinker is capable of crosslinking the water-soluble polymer; (c) a weak organic acid; and (d) water; wherein the treatment fluid is a crosslinkable polymer composition.