Halliburton Energy Services, Inc.

Landmark Graphics Corporation

Dwight David Fulton

Manisha Bhardwaj

Harold Grayson Walters

Michael Linley Fripp

Feng Liang

Zachary William Walton

Zachary R Murphree

Philip D Nguyen

Jeffrey Marc Yarus

Hongyu Luo

Jianfu Ma

Mohamed Yousef Soliman

Marko Maucec

Jianlei Sun

Ajish Sreeni Radhakrishnan Potty

Peyman Heidari

Loyd Eddie East

Julio Estuardo Vasquez

John M Terracina

Yogesh Kumar Choudhary

Youli Mao

Ajay Pratap Singh

Rama Subba Reddy Thavva

Richa Chauhan

Vikesh Singh Baghel

Darrell Gordy

Shane L Milson

Peng Zhang

Pooja Nitin Khanapurkar

Jaynee B Lafferty

Zoltan D Stiffel

Venu Madhav Reddy Amudala

Jon Matthew Orth

Srimoyee Bhattacharya

Md Monsur Alam

The disclosure is directed to methods to design and revise hydraulic fracturing (HF) job plans. The methods can utilize one or more data sources from public, proprietary, confidential, and historical sources. The methods can build mathematical, statistical, machine learning, neural network, and deep learning models to predict production outcomes based on the data source inputs. In some aspects, the data sources are processed, quality checked, and combined into composite data sources. In some aspects, ensemble modeling techniques can be applied to combine multiple data sources and multiple models. In some aspects, response features can be utilized as data inputs into the modeling process. In some aspects, time-series extracted features can be utilized as data inputs into the modeling process. In some aspects, the methods can be used to build a HF job plan prior to the start of work at a well site. In other aspects, the methods can be used to revise an existing HF job plan in real-time, such as after a treatment cycle, a pumping stage, or a time interval.

Hydraulic fracturing job plan real-time revisions utilizing collected time-series data

Hydraulic fracturing operation planning using data-driven multi-variate statistical machine learning modeling

Disclosed are systems and methods for obtaining input data comprising properties associated with at least one parent well and a child well associated with the at least one parent well, dividing the input data into a training data subset, a validation data subset, and a test data subset, selecting at least one machine learning model using the training data subset, the validation data subset, and the test data subset based on k-fold cross validation, tuning hyper parameters for each of the at least one machine learning model, and generating a learning output using the at least one machine learning model and the hyper parameters for each of the at least one machine learning model, the learning output indicating a test root-mean-square error (RMSE) and a training RMSE.

Systems and methods for forecasting well interference

Disclosed are systems and methods for obtaining an input sequence of input data features associated with a well for at least one time stamp during a period of time including well production rates for the well and well operation constraints for the well, dividing the input data features into a training data subset, a validation data subset, and a test data subset, building a well production model for the well using machine learning based on the training data subset, the validation data subset, and the test data subset, and generating a forecast for the well for a future period of time using the well production model, the forecast comprising a future well production rate for the well including at least one of an oil rate, a gas rate, and a water rate.

Systems and methods for forecasting well productivity

Disclosed are systems and methods for receiving historical production data associated with at least one hydraulic fracturing well, receiving time-series data associated with the at least one hydraulic fracturing well, the time-series data representing at least one type of data, receiving non-temporal data associated with the at least one hydraulic fracturing well, generating a machine learning model based on the historical production data, the time-series data associated with the at least one hydraulic fracturing well and based on an original job design during a first stage of the job at a particular hydraulic fracturing well, and the non-temporal data, determining an optimized job design for the particular hydraulic fracturing well having an objective function using a prediction based on the machine learning model, and implementing the optimized job design for the particular hydraulic fracturing well.

Systems and methods for real-time hydraulic fracture control

A wellbore trajectory survey, having an ordered plurality of survey points, is acquired. Each of the plurality of survey points has a measured depth, an inclination, and a geographic location of the point in the wellbore corresponding to the survey point. The wellbore trajectory survey is ordered on measured depth. The processor identifies a minimum lateral measured depth (min_LMD), a maximum lateral measured depth (max_LMD). The processor identifies a mid-lateral point (mid_LMP) in the plurality of survey points whose measured depth (mid_LMD) is greater than min_LMD and less than max_LMD.

Determining the location of a mid-lateral point of a horizontal well

A wellbore trajectory survey includes an ordered plurality of survey points, each of which has a measured depth, an inclination, and a geographic location. The wellbore trajectory survey is ordered on measured depth. A minimum lateral measured depth (min_LMD) as a measured depth of a first point in the ordered plurality of survey points for which the inclination exceeds an inclination threshold angle is identified. A maximum lateral measured depth (max_LMD) as a measured depth of a last point in the ordered plurality of survey points for which the inclination exceeds the inclination threshold angle is identified. The processor determines from the wellbore trajectory survey that the wellbore at measured depths between the min_LMD and the max_LMD exhibits porpoising into and out of a formation.

Detecting porpoising in a horizontal well

One example of well treatment design based on three-dimensional wellbore shape can be implemented as a computer-implemented method. Wellbore data including acoustic logging data that defines an internal shape of a wall of the wellbore at multiple locations around the perimeter of the wellbore can be received. A volume of an open hole portion of the wellbore that includes the multiple locations can be determined using the wellbore data. Using the volume of the open hole portion of the wellbore, a volume of a fluid loss treatment to treat the portion of the wellbore for well fluid loss can be determined.

Well treatment design based on three-dimensional wellbore shape

Degradable balls for downhole use may include an incompliant degradable polymer and a compliant filler material, the incompliant degradable polymer having an elastic modulus of about 2 GPa or greater, and the compliant filler material having an elastic modulus of less than about 2 GPa. Such degradable balls may be useful in sealing segments of a wellbore and actuating wellbore tools.

Degradable balls for use in subterranean applications

A method, system, and apparatus, including a program encoded on computer-readable medium, for detecting duplicate data files to be stored in a well job data archive includes identifying a well job data file for storage in a well job data archive and performing an initial duplicate check and a secondary duplicate check to determine if the well job data file is a duplicate of a data file stored in the well job data archive, as well as a quality assurance test of the file data. At least one of the well job data file or one or more of the data files stored in the well job data archive is identified as a duplicate data file based on the initial and secondary duplicate checks, and the well job data file is stored in the well job data archive in accordance with the initial and secondary duplicate checks and the identification of a duplicate data file.

Data file processing for a well job data archive

Downhole fluid treatment planning systems and methods should enable efficient creation, review, and editing of downhole fluid treatment plans. In some of the disclosed embodiments, a downhole fluid treatment planning method includes receiving downhole environment information. The method also includes generating a polar graph with multiple stage type wedges to visually represent fluid coverages or volumes of a downhole fluid treatment plan based on the downhole environment information. Meanwhile, a system for downhole fluid treatment planning includes a memory having software and an output device. The system also includes a processor coupled to the memory to execute the software. The software configures the processor to receive downhole environment information and to output a polar graph. The polar graph includes multiple stage type wedges to visually represent fluid coverages or volumes of a downhole fluid treatment plan based on the downhole environment information.

Methods and systems using a fluid treatment polar graph

Methods of making a degradable ball composition comprising a carboxylic acid, a fatty alcohol, a fatty acid salt, a fatty ester, or a combination thereof comprising the steps of: forming a thermoplastic mass, and allowing the thermoplastic mass to cool as to form a degradable ball that is introduced in subterranean treatments by a carrier fluid.

Degradable perforation balls and associated methods of use in subterranean applications

Methods and compositions that include a method of treating a subterranean formation comprising the steps of providing a carrier fluid comprising degradable balls that comprise a carboxylic acid, a fatty alcohol, a fatty acid salt, a fatty ester, a fatty acid salt, or a combination thereof, and introducing the carrier fluid to the subterranean formation during a treatment.

A method for monitoring a fracturing operation in a target well comprising extending a seismic sensor in a tubing string to a first position in an well offset from the target well. A coolant fluid is circulated through the tubing string for a predetermined time. The tubing string is retracted to a second uphole position such that the cooled seismic sensor is exposed in the offset wellbore. A seismic signal emitted during the fracturing operation of the target well is sensed in the offset well.

Growing community of inventors

Cypress, TX, United States of America

Dwight David Fulton