Halliburton Energy Services, Inc.

Paul Andrew Cooper

Glenn Andrew Wilson

Michael Thomas Pelletier

Li Gao

Arthur Cheng

Matthew Hui Chong

Thurairajasingam Rajasingam

Paul F Rodney

Weijun Guo

Batakrishna Mandal

YiJing Fan

Kristopher V Sherrill

Mark Vincent Collins

Ricardo Ortiz

Philip William Tracadas

Robert Wayne Pennison

Yijing Fan

Daniel Flores

Kevin R Kapka

George Stevenson

George Walter John Stevenson

George Walter Stevenson

A neutron tube. At least some of the illustrative embodiments including: generating, from a neutron tube, a first neutron burst having a first characteristic energy spectra; and generating, from the neutron tube, a second neutron burst having a second characteristic energy spectra different than the first characteristic energy spectra, the generating the second neutron burst within one second of generating the first neutron burst.

Method and system of a neutron tube

A system includes an electromagnetic logging tool that transmits an electromagnetic signal as the tool is conveyed along a borehole through a formation. The system further includes a processing system that measures a first signal level in response to the tool being at a first measured depth, determines a first conductance based on the first signal level, measures a second signal level in response to the tool being at a second measured depth greater than the first measured depth, the second measured depth and the first measured depth defining a formation interval there between, determines a second conductance based on the second signal level, and assigns a uniform resistivity value to the formation interval based on the first conductance and the second conductance.

Conductivity-depth transforms of electromagnetic telemetry signals

An acoustic tool, system, and method for performing down-hole measurements. An encoded pulse sequence is transmitted from an acoustic tool. First reflections are received from the encoded pulse sequences. The first reflections from the encoded pulse sequence are identified from a number of reflections of the encoded pulse sequence. Measurements are performed utilizing the first reflections of the encoded pulse sequence. Other systems and methods are presented.

Encoded driving pulses for a range finder

A system for self-tuning sonic transmitters which transmits a plurality of frequencies into a downhole formation, then identifies which of the transmitted frequencies generates the best response from the formation. The system then uses the best frequency identified for subsequent logging of formation data until a subsequent tuning sequence is initiated.

Self-tuning sonic transmitters

The shape and size of a borehole may be characterized downhole, using measurements of the borehole shape in conjunction with a catalog of shapes against which the measured shape is matched. A unique identifier for the measured borehole shape, and optionally a size parameter, may be transmitted to a surface facility, generally saving bandwidth compared with the transmission of the raw measured borehole-shape data. Alternatively or additionally, downhole measurements may be adjusted based on the measured shape.

Borehole shape characterization

An apparatus and a method for measuring a speed of sound in a fluid in a well bore may include a frame adapted to receive the fluid there through are provided. The apparatus includes an acoustic source mounted on the frame; an acoustic detector to measure a signal propagating through the fluid, the acoustic detector disposed proximate the frame at a known distance from the acoustic source; and a test circuit adapted to synchronize the acoustic detector with a signal propagating through the frame. A method to determine physical properties of a fluid in a geological formation including a shear wave anisotropy in the geological formation and the formation composition using the fluid density and the fluid speed of sound is also provided.

Method and apparatus for the downhole in-situ determination of the speed of sound in a formation fluid

An electromagnetic (EM) telemetry system with capacitive electrodes for use with downhole equipment is described. Embodiments of the EM telemetry system with capacitive electrodes include a downhole transceiver comprising an encoded signal transmitter, a downhole sensor disposed to monitor the downhole equipment, and an encoded signal receiver comprising one or more capacitive counter electrodes. The one or more capacitive counter electrodes receives a first encoded signal from the downhole transceiver, the encoded signal corresponding to a voltage measured between the counter electrode and a wellhead. A decoder and demodulator of the encoded signal receiver recovers information in the first encoded signal. A second encoded signal, which may include instructions for the downhole equipment, may be similarly encoded, modulated, and transmitted from the encoded signal receiver to the downhole transceiver.

Electromagnetic telemetry using capacitive electrodes

An electromagnetic (EM) telemetry system with telluric referencing for use with downhole equipment is described. Embodiments of an EM telemetry system with telluric referencing include a downhole transceiver comprising an encoded signal transmitter, a downhole sensor disposed to monitor the downhole equipment, the downhole sensor coupled to the transceiver, an encoded signal receiver, a reference receiver spaced apart from the encoded signal receiver and communicatively coupled to the encoded signal receiver, and a telluric voltage module coupled to one of the encoded signal receiver and the reference receiver. The telluric voltage module is communicatively coupled to the encoded signal receiver and the reference receiver to receive an encoded signal and a reference signal, respectively, which may include telluric noise. The telluric voltage module synchronizes the encoded signal and the reference signal, subtracts the reference signal from the encoded signal, and outputs a signal free from telluric noise.

Telluric referencing for improved electromagnetic telemetry

In some embodiments, an apparatus and a system, as well as a method and an article, may operate to receive a derived clock signal downhole, the derived clock signal being derived from a surface clock signal (associated with a surface clock), such that the frequency of the derived clock signal is less than the frequency of the surface clock signal. Further activity may include measuring the frequency of the derived clock signal in terms of an uncorrected downhole clock frequency (associated with a downhole clock) to provide a measured frequency equivalent, and correcting time measurements made using the downhole clock, based on the measured frequency equivalent, or based on an actual frequency of the downhole clock determined according to the measured frequency equivalent. Additional apparatus, systems, and methods are described.

Downhole clock calibration apparatus, systems, and methods

A first set of radiation detectors may be disposable on the a drill string, wherein the first set of radiation detectors are capable of detecting gamma radiation and neutron radiation; and a combined chemical source spaced from the first set of radiation detectors, wherein the combined chemical source comprises a gamma radiation emitting material and a neutron radiation emitting material. The first set of radiation detectors and combined chemical source may be used in methods for logging a wellbore.

Combined radioactive source for gamma-neutron tool

An electromagnetic telemetry system can be used for determining a resistivity of a portion of a wellbore drilled through a subterranean formation. For example, the electromagnetic telemetry system can include a computing device and a downhole transceiver positioned on a well tool in the wellbore. The computing device can receive, from the downhole transceiver, a signal indicating a load impedance across an electrically insulating segment of the downhole transceiver. The computing device can determine a resistivity associated with a portion of the wellbore based on the load impedance. The computing device can determine a corrected resistivity by modifying the resistivity associated with the portion of the wellbore using a correction factor.

Determining subterranean-formation resistivity using an electromagnetic telemetry system

Apparatus, systems, and methods may operate to emit acoustic pulses into a drilling fluid in a well bore, using a first acoustic transducer in a downhole tool, and detecting the acoustic pulses after reflection from the wall of the well bore, using a second acoustic transducer in the downhole tool. The faces of the first and second acoustic transducers are non-parallel. Further activities include emitting additional acoustic pulses into the drilling fluid using the second acoustic transducer, and detecting them using the second acoustic transducer. The acoustic velocity of the drilling fluid can be determined based on respective travel times. Additional apparatus, systems, and methods are described.

Acoustic velocity measurements using tilted transducers

A histogram includes a plurality of channels Ch1, Ch2, . . . ChN, which have respective channel numbers C1, C2, . . . CN. ChA with channel number CA, 1&#x3c;A&#x3c;N, representing a first peak, is associated with a known first-peak energy (EA). ChB with channel number CB, 1&#x3c;B&#x3c;N, A&#x2260;B, representing a second peak, is associated with a known second-peak energy (EB). A system of equations, including a first equation that is a function of EA and CA and a second equation that is a function of EB and CB, is solved for an energy scale, &#x3ba;, and a zero offset, E0. A function of EM, CM, &#x3ba;, and E0 is used to identify features in the histogram, wherein EM is an energy associated with the Mth channel in the histogram, and CM is the channel number of the Mth channel (ChM) in the histogram.

Stabilizing a spectrum using two points

Gamma pulse telemetry. At least some of the illustrative embodiments are methods including: reading data associated with a borehole penetrating an earth formation; encoding the data in a first plurality of gamma bursts, the encoding by an encoding system coupled within the drill string, and where the each gamma burst travels a first distance along the borehole; receiving the first plurality of gamma bursts by a receiver system coupled within the drill string; and decoding the first plurality of gamma bursts and thereby recovering the data.

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Houston, TX, United States of America

Paul Andrew Cooper