Halliburton Energy Services, Inc.

Andrew John Cuthbert

Joseph Eli Hess

Joe Eli Hess

Carl J Cramm

Arash Haghshenas

Thomas Earl Burky

Ronald Wayne Courville

Joe E Hess

Doug N Derr

Douglas N Derr

Ramesh K Raghunathan

Mary Anne Guinan

Joseph E Hess

Methods and system involving well control. In some embodiments, the system includes an injection spool coupled to a subsea wellhead including an inlet, a manifold in fluid communication with the inlet of the injection spool for mixing one or more components of a well control treatment composition, a first container for storing natural gas in fluid communication with the manifold, and a second container for storing nitrogen in fluid communication with the manifold.

Gas hydrate well control

A support arm can be positioned in an inner area of a tubular body. The support arm can extend from the inner surface of the tubular body to retain a sensor in flow from a wellbore blowout passing through the tubular body.

Instrumented tube for measuring flow from a wellbore blowout

A method includes collecting seismic survey data and processing the seismic survey data to identify subterranean conduit coordinates. The method also includes performing a conduit plugging operations using the identified subterranean conduit coordinates. A related system includes at least one seismic source and at least one seismic receiver to collect seismic survey data in response to at least one shot fired by the at least one seismic source. The system also includes a processing unit in communication with the at least one seismic receiver. The processing unit analyzes the collected seismic survey data to identify subterranean conduit coordinates for use with conduit plugging operations.

Methods and systems for identifying and plugging subterranean conduits

This disclosure provides a hybrid well capping stack system that uses a lower ram blow-out preventer (BOP) coupled to a gate valve-based capping stack that has first and second flowlines where the first flowline has a gate valve and the second flowline has a gate valve. At least one of the first and second flowlines is located on the frame to divert a flow of fluid laterally from a central flow axis of a wellbore.

Rapid response well control assembly

Methods and systems for evaluating integrity of a tubular located within a wellbore are provided. The method includes measuring an operation parameter of the wellbore, measuring a feature of the tubular two or more times to produce an integrity log each time the feature is measured, and determining a tubular integrity analysis for the tubular by using the integrity logs and the operation parameter. The tubular integrity analysis contains parameter limitations for the tubular. The method also includes determining if tubular integrity is within or outside the parameter limitations. If the tubular integrity is within the parameter limitations, then determine a duration of integrity for the tubular. If the tubular integrity is outside of the parameter limitations, then determine a location on the tubular for loss of tubular integrity.

Methods and systems for wellbore integrity management

In one or more embodiments, a system comprises a first (target) wellbore disposed in a formation, the first wellbore having a pressure imbalance therein causing an influx of formation fluids, a second (relief) wellbore disposed in the formation, a drill string disposed in the second wellbore, the drill string comprising a drill bit and a logging tool, and a wellbore ranging module comprising a processor and memory, the wellbore ranging module coupled to the drill string. The logging tool is configured to detect acoustic energy originating from the influx in the first wellbore and generate one or more signals associated with the detected acoustic energy. The wellbore ranging module is configured to receive, from the logging tool, the one or more signals associated with the detected acoustic energy and determine, using the received signals, a direction from the drill bit to the influx of the first wellbore.

Passive ranging using acoustic energy originating from a target wellbore

A method can include measuring temperature along a relief wellbore, thereby detecting a temperature anomaly in an earth formation penetrated by the relief wellbore, and determining a location of an influx into a target wellbore, based on the temperature anomaly detecting. A thermal anomaly ranging system for use with a subterranean well can include a temperature sensor in a relief wellbore that penetrates an earth formation, the temperature sensor detecting a temperature anomaly in the formation, and the temperature anomaly being caused by an influx into a target wellbore. Another method can include measuring optical scattering in an optical waveguide positioned in a relief wellbore, thereby detecting a temperature anomaly in an earth formation penetrated by the relief wellbore, and determining a location of an influx into a target wellbore, based on the temperature anomaly detecting.

Downhole thermal anomaly detection for passive ranging to a target wellbore

A method of establishing fluid communication between wellbores can include forming a flow path from one wellbore to another wellbore, a flow area of the flow path increasing in a direction from the first wellbore toward the second wellbore. An explosive assembly for use in a well can include an explosive device having multiple explosive charges, the explosive charges producing longitudinal shock waves that collide with each other and result in a laterally directed shock wave, and a shield that focuses the laterally directed shock wave into a predetermined angular range of less than 360 degrees. A method of establishing fluid communication between wellbores can include forming a flow path from one wellbore to another wellbore, the flow path intersecting an uncased portion of the second wellbore.

Establishing communication downhole between wellbores

A well system includes a target wellbore that penetrates a subterranean formation and a relief wellbore drilled toward the target wellbore and a target intercept location where a fluid flows into the target wellbore from the subterranean formation. A bottom hole assembly is coupled to a drill string extended into the relief wellbore and includes a fiber optic ranging assembly having one or more fiber optic sensors positioned on a tubular member. The fiber optic sensors measure at least one of acoustic energy and thermal energy emitted by the fluid as it flows into the target wellbore. A computer system is communicably coupled to the one or more fiber optic sensors to process measurements of the fluid obtained by the one or more fiber optic sensors.

Passive ranging to a target well using a fiber optic ranging assembly

In accordance with embodiments of the present disclosure, systems and methods for establishing hydraulic communication between a relief wellbore and a target wellbore during relief well applications are provided. Present embodiments include a perforating gun that uses an explosively formed penetrator (EFP) to establish hydraulic communication between a relief well and the target well for well kill operations. The EFP may be detonated downhole according to the Misznay-Schardin effect, thereby releasing a projectile toward the target well to form a relatively large hole through the casing/cement between the wellbores. The EFP may be positioned in a desired orientation with respect to the target well, in order that the projectile may be directed from the relief well directly into the target well. In some embodiments, the disclosed perforating gun may include several EFP charges positioned along one side of the gun at approximately 0 to 10 degree phasing from each other.

Establishing hydraulic communication between relief well and target well

A magnetic marking method includes drilling a borehole and marking a position along an uncased section of the borehole with a magnetic marker comprising a magnetic rare earth alloy. A magnetic marker for open hole use includes an unconsolidated mass of high remanence, magnetized material that comprises a magnetic rare earth alloy. The magnetic marker for open hole use also includes a suspension fluid suited for conveying the magnetized material through a drill string bore into an open borehole. A magnetic marker for a casing terminus includes a magnet comprising a magnetic rare earth alloy and an attachment mechanism that secures the magnet to a casing shoe. Such magnetic markers for open hole use or a casing terminus can be used for borehole intersection operations.

Rare earth alloys as borehole markers

A blowout rate correction system comprises a sensor and a processor in communication with the sensor. The sensor is to measure sound characteristics associated with an exit point of a borehole. The processor is to determine a blowout rate of hydrocarbons exiting the borehole based on the sound characteristics. In some embodiments, the processor activates a device when the blowout rate exceeds a selected threshold. Additional apparatus, methods, and systems are disclosed.

Blowout rate correction methods and systems

A method can include measuring microseismic activity in a relief wellbore, thereby detecting a microseismic event in an earth formation penetrated by the relief wellbore, and determining a location of an influx into a target wellbore, based on the microseismic event detecting. A microseismic ranging system for use with a subterranean well can include at least one microseismic sensor in a relief wellbore that penetrates an earth formation, with the microseismic sensor detecting a microseismic event in the formation, the microseismic event being caused by an influx into a target wellbore. Another method can include measuring optical scattering in an optical waveguide positioned in a relief wellbore, thereby detecting a microseismic event in an earth formation penetrated by the relief wellbore, and determining a location of an influx into a target wellbore, based on the microseismic event detecting.

Downhole microseismic detection for passive ranging to a target wellbore

A method of severing a tubular structure can include producing a stream of plasma between a plasma arc cutter and the tubular structure, and displacing the plasma arc cutter relative to the tubular structure, thereby cutting through the tubular structure. A plasma arc cutting apparatus can include a transport vehicle, a boom extending from the transport vehicle, at least one plasma arc cutter, and at least one actuator that displaces the plasma arc cutter relative to the boom. Another method of severing a tubular structure can include conveying a plasma arc cutter to the tubular structure with a transport vehicle, and displacing the plasma arc cutter relative to the transport vehicle.

Growing community of inventors

Spring, TX, United States of America

Andrew John Cuthbert