Western Atlas International, Inc.

Dresser Industries, Inc.

Royal Wireline, Inc.

Norman R Carlson

James C Barnette

Edward W Lanuke

Raymond E Roesner

Vernie C McWhirter

James E Pickett

James M Johnston

Mohammad J Davarzani

Steven B Easton

Method and apparatus are disclosed for determining the water cut of an oil-water flow in a wellbore having a known deviation angle less than 90. A first step includes generating a set of predicted response curves where each response curve relates discrete selected values of the water cut to test values representative of a value of the flow mixture functionally related to measured responses of a selected logging instrument capable of distinguishing between the water and oil phases of the flow mixture for a selected oil-water total flow rate and at a borehole deviation within a selected range of deviation values that include the known borehole deviation. Then the selected logging instrument combination is introduced into the borehole for measuring the total flow rate of the oil-water mixture and the values representative of the responses of the selected logging instrument distinguishing between the oil and water phases of the oil-water mixture. A value functionally related to the measured value representative of the responses of the selected logging instrument is generated. From the set of predicted response curves an estimated value of the water cut of the oil-water mixture at the measured borehole total flow rate of the oil-water mixture is determined in response to the generated value functionally related to the measured value representative of the responses of the selected logging tool.

Method and apparatus for determining flow rates in multi-phase fluid

A method for profiling of a gas and liquid producing wells comprising compiling calibration data from measuring instruments within non-in situ test equipment, valuing downhole gas and liquid density, determining average values for downhole instrument measurements and predicting, utilizing the above information, a percent of total gas flow and a percent of total liquid flow at a downhole depth.

Method for gas/liquid well profiling

A method for evaluating the extent of deterioration of pipes whereby an inspection instrument is passed through a length of casing to determine the extent of corrosive deterioration. The resulting measurements generated by the inspection instrument are processed to exclude those responses caused by the structural configuration of the casing length under inspection. The remaining responses are then analyzed to compile a detailed interpretation of the measurements including specific information regarding the state of deterioration of the length of casing under inspection.

Method of evaluating the condition of tubular goods

A method of identifying the presence, type and extent of internal casing wear and distinguish worn casing from various types of unworn casing. Two inspection instruments are tied together in the combination traverses a section of casing where information on internal wear is desired. The first inspection instrument generates two signals related to the minimum and maximum wall thickness present at each location within the casing section. The second inspection instrument generates a signal related to the degree of phase shift at each location of the casing section. The present invention analyzes these three signals and generates a differential crossplot whereby for each location of the casing section, a point-pair is plotted, both points of the point-pair having the same phase shift curve differential (calculated from the degree of the phase shift data series) as the X-coordinate and a maximum and minimum radius curve differential (calculated from the minimum and maximum wall thickness data series respectively) as respective Y-coordinates. Analysis of the differential crossplot may then be made, either along or in conjunction with the calculated round casing line to identify the presence, type and extent of internal casing wear and distinguish worn casing from various types of unworn casing.

Method and apparatus for measuring internal casing wear

A method of determining the location and dimensions of collars present along a section of casing. An inspection instrument is passed through the casing section generating an electromagnetic wave which permeates the casing. The phase shifted electromagnetic wave is detected by a receiver and a data string comprising the degree of phase shift present at each point along the casing section is created. The data string is processed to identify the location of collars present along the casing section. Upon the identification of a collar, a series of pattern recognition interrogations are used to confirm the collar location and to determine the collar's dimensions.

Method of detecting collars using computerized pattern recognition

A method of determining the presence of channels in the cement behind a well casing utilizing the temperature profiles of the well. In a first embodiment rate coefficients indicative of the rate of temperature change along a zone of investigation are calculated from the geothermal gradient, flowing temperature profile and at least one shut-in temperature profile. These rate coefficients are plotted versus depth, with inconsistencies in the valves of the rate coefficients being indicative of the presence of channels. In a second embodiment rate coefficients are calculated over a well bonded zone of the well casing and utilized to predict shut-in temperatures along the zone of investigation. Differences in the predicted and actual shut-in temperatures is further indicative of the presence of channels.

Analysis of cement bonding utilizing temperature profiles

A method and system for well logging provide indications of the characteristics of fluid flow behind pipe. An acoustic listening device is positioned within a pipe in proximity to suspected fluid flow behind the pipe. Acoustic energy resulting from the fluid flow is detected and separated into at least two frequency groups or ranges; the first comprising acoustic energy of relatively low frequency and the second comprising acoustic energy of relatively higher frequency. The relative distribution of acoustic energy between the two frequency groups provides an indicator of the nature of the fluid flow behind the pipe.

Method and apparatus for evaluating flow characteristics of fluid behind

In a well containing a multi-phase fluid flow regime is disposed an elongated body member with a funnel configuration attached thereto for the purpose of collecting and mixing the multiple fluid phases. An aperture is provided in the body member, proximate to the apex of the funnel configuration, to allow dicharge of the substantially homogeneous mixture of the fluid phases from the funnel through a passage in the body member. A rotor is acted upon by the flow of this mixture and generates a signal representative of the mixture flow rate. A portion of the mixture then enters a chamber in the elongated body member wherein a measurement is made of the degree of penetration of the mixture achieved by gamma radiation, thereby yielding a measurement representative of the density of the mixture. The flow rates and volumetric fractions of each of the individual phases may then be determined in accordance with the mixture density and total flow rate.

Method and apparatus for measurement of fluid density and flow rates in

A reference is established indicating the functional relation between differing proportions of one fluid phase within a mixture of a plurality of fluid phases to the dielectric response of that mixture. Measurements are taken within a well wherein the well fluid consists of multiple fluid phases, of the flow rate, density and dielectric response of the well fluid. The dielectric response measurement is related to the established reference to determine the apparent proportion or volumetric fraction of one fluid phase of the well fluid. The density measurement is utilized to determine the volumetric fraction of the same phase of the well fluid. These equivalent volumetric fraction determinations are utilized to adjust the established reference in response to the density-determined volumetric fractions such that subsequent dielectric response measurements within the well fluid may be correlated to such adjusted reference and thus may be translated into appropriate volumetric fraction values with improved accuracy. These volumetric fraction determinations may then be related to the flow rate measurement made within the well to obtain the flow rates of the individual phases of the well fluid at the depths at which the described measurements were made.

Growing community of inventors

Houston, TX, United States of America

Norman R Carlson