Halliburton Energy Services, Inc.

Philip Edmund Fox

Gary James Frisch

Mark Anton Proett

Michael E Shade

Gregory N Gilbert

Fnu Suparman

Dominic Anh Tran

Josiah Wood

Greg Gilbert

Ronnie Kennedy

Ben Gary

Christopher Michael Jones

Dingding Chen

Jack Gammill Clemens

John Andrew Quirein

David Russ Larimore

Jerome Allen Truax

Jim Taylor Hill

Philip William Tracadas

Arthur Chuen Hon Cheng

Heru Rubin

Michael Jason Englar

John Douglas Lauchner

A method includes introducing a tool string into a wellbore having material disposed in an annular region surrounding the casing. Obtaining acoustic refracted waveform measurements of the material from a cement bond logging tool, obtaining ultrasonic measurements of the material from a circumferential acoustic scanning tool, obtaining gamma radiation measurements scattered from the material from a circumferential spectral density logging (RSDX) tool by emitting gamma radiation from a radioactive source in a rotating portion of the RSDX and detecting scattered gamma radiation using near and far spectral density detectors, and obtaining thermal neutron radiation measurements scattered from the material from a dual spaced neutron logging tool. A computer obtains measurements and generates a deliverable that includes one or more cross plots that identify a compositional equivalent of the material in an entire circumference of the wellbore.

Rotating spectral density tool for behind pipe evaluation

A method includes introducing a tool string into a wellbore having annular material disposed in an annulus defined between casing and the wellbore. Obtaining acoustic refracted waveform measurements of the annular material from a cement bond logging tool, obtaining ultrasonic measurements of the annular material from a circumferential acoustic scanning tool, obtaining gamma radiation measurements scattered from the annular material from a spectral density logging tool, and obtaining thermal neutron radiation measurements scattered from the annular material from a dual spaced neutron logging tool. Obtained measurements may then be collected and computed with a computer and a deliverable is generated that includes one or more cross plots providing a compositional equivalent of the annular material.

Behind pipe evaluation techniques for well abandonment and complex annular environments

A method for evaluating a cement sheath in a wellbore, in some embodiments, comprises transmitting sonic or ultrasonic waves from a logging tool disposed in a wellbore, receiving reflected waves at the logging tool and recording waveforms based on the received waves, processing the waveforms to determine average absolute value amplitude data for each of a plurality of zones, and determining a number using average absolute value amplitude data for a first of the plurality of zones and average absolute value amplitude data for a second of the plurality of zones.

Using amplitude ratio curves to evaluate cement sheath bonding in multi-string downhole environments

Systems and methods for downhole formation testing based on the use of one or more elongated sealing pads disposed in various orientations capable of sealing off and collecting or injecting fluids from elongated portions along the surface of a borehole. The various orientations and amount of extension of each sealing pad can increase the flow area by collecting fluids from an extended portion along the surface of a wellbore, which is likely to straddle one or more layers in laminated or fractured formations. Various designs and arrangements for use with a fluid tester, which may be part of a modular fluid tool, are disclosed in accordance with different embodiments.

Downhole formation testing and sampling apparatus

An example apparatus for downhole cement inspection may include a tool body and an acoustic transmitter coupled to the tool body. An acoustic receiver may be coupled to the tool body at a first distance from the acoustic transmitter. A first array of acoustic receivers may be coupled to and positioned around a circumference of the tool body at a second distance from the acoustic transmitter. The second distance may be greater than the first distance. The acoustic receiver may be one receiver of a second array of acoustic receivers coupled to and positioned around the circumference of the tool body at the first distance. The first distance may be approximately three feet and the second distance may be approximately five feet.

Circumferential array borehole evaluation tool

A method for generating a cement bond log, in some embodiments, comprises transmitting sonic or ultra-sonic waves in multiple directions from a logging tool disposed in a wellbore, receiving reflected waves at the logging tool and recording waveforms based on the received waves, processing the waveforms to determine numerical values that indicate a degree of bonding associated with multiple portions of a cement sheath disposed in the wellbore, aggregating the numerical values, and generating a composite image based on the aggregated numerical values.

Peak analysis of multi-directional sonic an ultrasonic waveforms for cement bond logging

Casing removal operations may utilize an analytical model to the estimate the total force to (1) break bonding between a cut casing and the annular materials contained between the cut casing and the surrounding borehole and (2) pull the cut casing upward through the borehole while taking into account frictional forces inside and outside the cut casing, shear forces, and the like. Such models may further predict the casing overpull and total tension needed to extract the cut casing from the borehole. Using these models in conjunction with the specifications of the casing retrieval equipment may allow for determining the cutting depth for producing the cut casing with higher accuracy than previously available.

Behind pipe evaluation of cut and pull tension prediction in well abandonment and intervention operations

Various embodiments include apparatus and methods to provide pipe analysis, annulus analysis, or one or more combinations of pipe analysis and annulus analysis with respect to one or more pipes in a wellbore. The analysis can include application of clustering and classification methods with respect to the status and the environment of the one or more pipes in the wellbore. In various embodiments, the clustering and classification can be used in characterizing borehole annular material including cement bond quality evaluation. Additional apparatus, systems, and methods are disclosed.

Apparatus and methods of analysis of pipe and annulus in a wellbore

In modeling passage of an elongate well tool through an interval of a well an adaptive machine learning model executed on a computing system receives a first set of inputs representing a plurality of characteristics of the well tool and a second set of inputs representing a plurality of characteristics of the well. The adaptive machine learning model also receives historical data representing a plurality of other well tools passed through a plurality of other wells and a plurality of characteristics of the other well tools and the other wells. The adaptive machine learning model matches the historical data with at least a portion of the first and second sets of inputs, and determines, based on the matching whether the well tool can pass through the interval of the well.

Modeling passage of a tool through a well

In modeling operation of a well tool in applying a force to a device in a well, a computing system receives inputs representing a plurality of geometric characteristics of the well tool. The computing system also receives inputs representing a plurality of geometric characteristics of the well. The computing system determines based on the geometric characteristics of the well tool and the well, a predicted reaction force on a portion of the well tool that affects operation of the well tool in applying force to the device. The predicted reaction force is due to contact between a surface associated with the well tool and a surface of the well.

Modeling operation of a tool in a wellbore

Systems and methods for downhole formation testing based on the use of one or more elongated sealing pads capable of sealing off and collecting or injecting fluids from elongated portions along the surface of a borehole. The modified sealing pads increase the flow area by collecting fluids from an extended portion along the surface of a borehole, which is likely to straddle one or more layers in laminated or fractured formations. A tester device using the elongated sealing pads can be deployed and withdrawn using an extendible element pressing the pads to the borehole. Various designs and arrangements for use with a fluid tester, which may be part of a modular fluid tool, are disclosed in accordance with different embodiments.

Formation testing and sampling apparatus and methods

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.

Formation characterization using wellbore logging data

Systems and methods for downhole formation testing based on the use of one or more elongated sealing pads capable off sealing off and collecting or injecting fluids from elongated portions along the surface of a borehole. The modified sealing pads increase the flow area by collecting fluids from an extended portion along the surface of a borehole, which is likely to straddle one or more layers in laminated or fractured formations. A tester device using the elongated sealing pads can be deployed and withdrawn using an extendible element pressing the pads to the borehole. Various designs and arrangements for use with a fluid tester, which may be part of a modular fluid tool, are disclosed in accordance with different embodiments.

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Covington, TX, United States of America

Philip Edmund Fox