Halliburton Energy Services, Inc.

Joshua Lane Camp

Mikko K Jaaskelainen

Ronald Glen Dusterhoft

Tyler Austen Anderson

Srinath Madasu

Ian Bradford Mitchell

Ubong Akpan Inyang

William Owen Alexander Ruhle

Ajish Potty

Tirumani N Swaminathan

Jim Basuki Surjaatmadja

Stanley Vernon Stephenson

Timothy Holiman Hunter

Avi Lin

Eric James Davis

Vladimir Nikolayevich Martysevich

Henry Clifford Bland

Dinesh Ananda Shetty

Aaron Gene Russell

Janette Cortez Montalvo

Baidurja Ray

Chaitanya Mallikarjun Karale

Jie Bai

Seyed Omid Razavi

Mikko Jaaskelaninen

Karan Dhuldhoya

Tim Holiman Hunter

A method of controlling a pumping sequence of a fracturing fleet at a wellsite. A managing application executing on a computer in the control van can retrieve the pumping sequence from a local or remote storage computer. The managing application can establish an electronic communication link to receive sensor data from a plurality of fracturing units. The managing application can control the plurality of fracturing units with a stage script with multiple sequential instructions for a pumping stage of a pumping sequence while receiving one or more periodic data sets from the plurality of fracturing units wherein the data sets are indicative of the current state of the pumping stage of the pumping sequence.

Method for equipment control

Aspects of the subject technology relate to systems and methods for controlling a hydraulic fracturing job. Systems and methods are provided for receiving diagnostics data of a hydraulic fracturing completion of a wellbore, accessing a fracture formation model that models formation characteristics of fractures formed through the wellbore into a formation surrounding the wellbore during the hydraulic fracture completion with respect to surface variables of the hydraulic fracturing completion, selecting one or more subsurface objective functions from a plurality of subsurface objective functions for changing one or more of the formation characteristics of the fractures, and applying the fracture formation model based on the diagnostics data to determine values of the surface variables for controlling the formation characteristics of the fractures to converge on the one or more subsurface objective functions.

Fracturing control

Aspects of the subject technology relate to systems and methods for controlling a hydraulic fracturing job. Systems and methods are provided for receiving diagnostics data of a hydraulic fracturing completion of a wellbore, accessing a fracture formation model that models formation characteristics of fractures formed through the wellbore into a formation surrounding the wellbore during the hydraulic fracturing completion with respect to surface variables of the hydraulic fracturing completion, selecting one or more subsurface objective functions from a plurality of subsurface objective functions for changing one or more of the formation characteristics of the fractures, the one or more subsurface objective functions including an objective function for cluster efficiency, the objective function for cluster efficiency including flow distribution throughout a plurality of clusters of perforations, and applying the fracture formation model based on the diagnostics data to determine values of the surface variables.

Cluster efficiency operation control

A system and method to determine closure pressure in a wellbore that can include, flowing a fracturing fluid into the wellbore during a fracturing operation of at least one stage and forming a fracture, sensing fluid pressure and a flow rate of the fracturing fluid during the fracturing operation and communicating the sensed data to a controller, plotting data points of the sensed data to a visualization device which is configured to visually present the data points to an operator as a plot, fitting a curve to the data points which represent statistically-relevant minimum pressure data at various flow rates, determining an intercept of the first curve with a zero flow rate axis of the plot, determining the closure pressure based on a pressure value of the intercept, and determining an average fracture permeability based on the closure pressure.

Determining wellbore parameters through analysis of the multistage treatments

System and methods of controlling fracture growth during multi-well stimulation treatments. The flow distribution of treatment fluid injected into first and second well formation entry points along multiple wellbores is monitored during a current stage of a multi-well, multistage stimulation treatment. Upon determining the fracture growth and/or monitored flow distribution meets a threshold, a remainder of the current stage is partitioned into a plurality of treatment cycles and at least one diversion phase. A portion of the fluid to be injected into the first well and/or second well formation entry points is allocated to each of the treatment cycles of the partitioned stage. The treatment cycles are performed for the remainder of the current stage using the treatment fluid allocated to each treatment cycle, wherein the flow distribution is adjusted so as not to meet the threshold.

Flow rate optimization during simultaneous multi-well stimulation treatments

System and methods of controlling fluid flow during reservoir stimulation treatments are provided. A flow distribution of treatment fluid injected into formation entry points along a wellbore path is monitored during a current stage of a multistage stimulation treatment. Upon determining that the monitored flow distribution meets a threshold, a remainder of the current stage is partitioned into a plurality of treatment cycles and at least one diversion phase for diverting the fluid to be injected away from one or more formation entry points between consecutive treatment cycles. A portion of the fluid to be injected into the formation entry points is allocated to each of the treatment cycles of the partitioned stage. The treatment cycles are performed for the remainder of the current stage using the treatment fluid allocated to each treatment cycle, wherein the flow distribution is adjusted so as not to meet the threshold.

Real-time monitoring and control of diverter placement for multistage stimulation treatments

The disclosure presents a process for calibrating a diversion model for a treatment stage of a hydraulic fracturing well site. The process can pump a portion of the proppant into the wellbore, flush the wellbore with clean HF fluid, and then perform a diagnostic test to determine a near-wellbore (NWB) flow resistance parameter. Next, diverter material can be distributed into the wellbore and the amount of diverter material delivered to each active perforation cluster can be estimated. A second diagnostic test can be performed followed by computing diversion model parameters such as a near-wellbore zone length parameter for perforation clusters capable of receiving HF fluid. In another aspect, a system is disclosed that can direct operations of a well site pump and collect data from surface and downhole diagnostic sensors, and then use the collected data for the diversion model calibration process.

Calibrating a diversion model for a hydraulic fracturing well system

Aspects of the subject technology relate to systems, methods, and computer-readable media for controlling a hydraulic fracturing job. Diagnostics data of a hydraulic fracturing completion of a wellbore can be received. A fracture formation model that models formation characteristics of fractures formed through the wellbore into a formation surrounding the wellbore during the hydraulic fracturing completion with respect to surface variables can be accessed. A subsurface objective function of fracture complexity can be selected from a plurality of subsurface objective functions for changing one or more of the formation characteristics of the fractures. The fracture formation model can be applied based on the diagnostics data to determine values of the surface variables for controlling the formation characteristics of the fractures to converge on the subsurface objective function of fracture complexity. As follows, a fracture completion plan can be formed based on the values of the surface variables.

Fracture complexity operation control

System and methods of controlling diverter placement during stimulation treatments are provided. Data relating to at least one downhole parameter is obtained for a current treatment stage within a subsurface formation. A response of the diverter to be injected during a diversion phase of the current stage on the downhole parameter is estimated, based on the obtained data and a diagnostic data model. Values for diversion control parameters are calculated, based on the estimated response. As the diverter is injected into the formation, an actual response of the diverter is monitored. Upon determining that a difference between the actual and estimated response exceeds an error tolerance threshold, the model is updated. The model is further updated over subsequent iterations of the diversion phase when the actual response is less than the estimated response. Subsequent diversion phases are performed over a remainder of the current stage, based on the updated model.

Aspects of the subject technology relate to systems and methods for controlling a hydraulic fracturing job. A fracturing completion model can be applied to identify a plurality of possible fracturing completion plans for completing one or more wellbores at a target completion. The plurality of possible fracturing completion plans can include varying values of fracturing completion parameters and/or reservoir parameters. Completion characteristic data of the one or more wellbores can be gathered in response to application of at least a portion of a fracturing completion plan of the possible fracturing completion plans. Further, the completion characteristic data can be used to determine whether to apply a different fracturing completion plan of the possible fracturing completion plans. In turn, if it is determined to apply the different fracturing completion plan, then the method can include facilitating switching to the different fracturing completion plan in completing the one or more wellbores.

Hydraulic fracturing modelling and control

A flow distribution may be monitored to one or more clusters of perforations. Plugging criteria may be identified based on the flow distribution and characteristics associated with perforation plugs to be dropped into a wellbore associated with the subsurface formation may be determined based on the flow distribution, characteristics of the one or more clusters, and the plugging objective. The perforation plugs may be dropped into the wellbore. The perforation plugs may have tracers which indicate whether the perforation plugs reached a location associated with the one or more clusters.

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Friendswood, TX, United States of America

Joshua Lane Camp