Halliburton Energy Services, Inc.

Srividhya Sridhar

Dinesh Ananda Shetty

Michael Linley Fripp

Stephen Michael Greci

Xiang Wu

William Owen Alexander Ruhle

Xusong Wang

William Owen Ruhle

Ubong Akpan Inyang

Peter Reid Maher

Jie Bai

William Ruhle

Shahab Jamali

Joseph Andrew Romani

A system and method to predict or detect screen outs by measuring pressure conditions in the well in real-time, and that conducts mitigation of the condition. Pressure responses of the well are detected during a fracture operation. The system processes the pressure responses by removing the effects of non-screen out related factors. A mathematical model is applied to the pressure responses to detect or predict the screen out. In response to the screen out detection or prediction, corrective action may be initiated.

Detection and prediction of screen outs during downhole fracturing operations

A magnet shield for use with a magnetic scale inhibitor includes a barrier configured for positioning at a location between the magnetic scale inhibitor and a flowbore for at least a first time period. The flowbore is configured for flow of a fluid. The barrier is: degradable in the fluid, such that, after the first time period, the barrier is no longer present at the location; and/or shiftable, such that, after the first time period, the barrier can be shifted away from the location. During the first time period, the barrier reduces or eliminates attraction of ferromagnetic particles to magnets of the magnetic scale inhibitor. A magnetic scale inhibitor tool comprising the magnet shield and a methods of utilizing the magnet shield and the magnetic scale inhibitor tool comprising the magnet shield are also provided herein.

Removable covers for magnetic scale inhibitors

An apparatus to be positioned in a wellbore formed in a subsurface formation. The apparatus comprises a flow control device to restrict a fluid flowing from the subsurface formation and into a tubular string positioned in the wellbore. The apparatus comprises a magnetic assembly positioned proximate the flow control device.

Magnetic inflow control device to inhibit scale production in a wellbore

Processes for mitigating wellbore screen-out. The processes can automatically determine an onset of wellbore screen-out by analyzing corrected pressure data from the at least one pressure sensor, select at least one type of mitigation action based on the automatic determination of the onset of the wellbore screen-out, and mitigate the wellbore screen-out with the selected at least one type of mitigation action.

Automatic real time screen-out mitigation

Systems and methods generally relate to monitoring, evaluating, and controlling fracture geometry during a hydraulic fracturing operation, in real time. A method comprises measuring a signal representing a condition in a wellbore; inputting the signal into a model for estimating a dimension of a dominant fracture; determining the dimension of the dominant fracture; determining a target dimension for the dominant fracture; and minimizing a difference between the dimension of the dominant fracture and the target dimension in real time, by adjusting at least an injection pressure or flow rate of a hydraulic fracturing fluid into the wellbore.

Real-time fracture monitoring, evaluation and control

A magnet shield for use with a magnetic scale inhibitor includes a barrier configured for positioning at a location between the magnetic scale inhibitor and a flowbore for at least a first time period. The flowbore is configured for flow of a fluid. The barrier is: degradable in the fluid, such that, after the first time period, the barrier is no longer present at the location; and/or shiftable, such that, after the first time period, the barrier can be shifted away from the location. During the first time period, the barrier reduces or eliminates attraction of ferromagnetic particles to magnets of the magnetic scale inhibitor. A magnetic scale inhibitor assembly comprising the magnet shield and a methods of utilizing the magnet shield and the magnetic scale inhibitor assembly comprising the magnet shield are also provided herein.

When a child well is hydraulically fractured near the depleted reservoir volume surrounding a previously produced parent well, it is economically efficient to deliver proppant to the formation volume and fractures not reached by the parent well. A fracture length, which is the distance fluid travels from the child well to the depleted region, is calculated as a function of fracture stage. From identified trends in fracture length, fracture length for future stages can be predicted. Based on predicted fracture length, the slurry or treatment volume to cause well interference can be estimated. Proppant concentration or fracturing stage design can be adjusted so that the well interference volume is larger than the treatment volume and proppant is efficiently delivered to the child well fractures.

Real time parent child well interference control

A process to determine whether a leak-off event is occurring during the treatment stage of an active borehole. The leak-off event data, such as the severity or magnitude of the potential leak-off, can be communicated to other systems to adjust the treatment stage, the fluid composition, the fluid pressure, or the fluid flow rate. Diverter material can be added to the fluid. The monitoring of the leak-off event can occur over a time interval, such as the time of the treatment stage and periodic adjustments to the treatment stage can be implemented. The leak-off event can be identified when a fluid pressure slope indicates an overall increase in pressure in an adjacent borehole or if the amount of fluid entering an adjacent borehole exceeds a leak-off threshold.

Estimate active-adjacent borehole interference severity

A system comprising engine driven pumps, control units, a rate control algorithm, and a trained algorithmic model. The control units store operation variables for the engine driven pumps. The rate control algorithm includes an instruction set to read the operation variables for the engine driven pumps. The instruction set comprises a trained algorithmic model with a parameter space based on historical operation variables. The trained algorithmic model determines an optimal distribution rate based on an objective. The instruction set generates rate control variables based on the determined optimal distribution rate. Each rate control variable comprises a selected control unit identifier and a rate value. The instruction set distributes each rate control variable based on the selected control unit identifier. The trained algorithmic model determine the optimal distribution rate using an objective that defines a desired mixture between a first fuel and a second fuel.

Rate control algorithm having a trained algorithmic model for optimizing fuel distribution

Systems and methods of the present disclosure generally relate to monitoring, evaluating, and controlling fracture geometry during a hydraulic fracturing operation, in real time. A method comprises measuring a signal representing a condition in a wellbore; inputting the signal into a model for estimating a dimension of a dominant fracture; determining the dimension of the dominant fracture; determining a target dimension for the dominant fracture; and minimizing a difference between the dimension of the dominant fracture and the target dimension in real time, by adjusting at least an injection pressure or flow rate of a hydraulic fracturing fluid into the wellbore.

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Bellaire, TX, United States of America

Srividhya Sridhar