Weatherford Technology Holdings, LLC

Reeves Wireline Technologies Limited

Jian Huang

Clayton S Smith

Ovunc Mutlu

Mojtaba Pordel Shahri

Francisco E Fragachan

Rajesh Kumar Saini

Leonid Vigderman

Chih-Chau Hwang

Kern L Smith

Mohammadreza Safariforoshani

Kedar M Deshpande

Duane Treybig

Mathew M Samuel

Clayton Smith

Branden Ruyle

Sunil Lakshminarayanan

David Eccles

Mohammad Reza Safariforoshani

A fluid design with enhanced proppant-carrying capacity utilizes a low-viscosity fluid with high proppant carrying capacity and low required power for injection into a hydrocarbon-bearing, subterranean formation. A preferred viscosifying agent that comprises a copolymer polymerized from an acrylic acid monomer and a monomer selected from: a) at least one carboxylic acid monomer; b) at least one Cto Calkyl ester and/or at least one Cto Chydroxyalkyl ester of acrylic acid or methacrylic acid; c) one crosslinking monomer; and optionally d) at least one &#x3b1;,&#x3b2;-ethylenically unsaturated monomer, may be used to produce a fracturing fluid that has the pumpability of a slick water fluid and the proppant-carrying ability of a cross-linked gel. An optimization process to optimize hydraulic fracture design evaluates and quantifies the proppant-carrying capacity of the invented fluid and its impact in the proppant transport during fracturing.

Fracturing method using low-viscosity fluid with low proppant settling rate

The disclosure pertains to the increasing the amount of stimulated efficiency and production from a given well area by determining a number of diverter slugs and the timing for the injection of the slugs for the given well area. A number of data sets are determined using Monte Carlo analysis, each data set including a quantity of diversion slugs and the timing for the injection of the diversion slugs. A simulation is performed on a plurality of the data sets to determine the production outcome of employing the data set in a stimulation job. The results of the simulation are used to determine the optimized data set for the stimulation job.

Systems and methods for optimization of the number of diverter injections and the timing of the diverter injections relative to stimulant injection

A method of calculating the unconfined compressive strength (UCS) of subterranean rock having a borehole formed or being formed therein comprises the steps of:

Method of and apparatus for calculating UCS and CCS

The disclosure pertains to the determining the efficiency of stimulation operations in a hydrocarbon well. Stimulation is performed in a hydrocarbon well and various data is obtained therefrom. The data is used to develop a simulation of fluid flow in the well and the simulation is used to model a synthetic tracer log, which corresponds to a modeled level of efficiency. Numerous synthetic tracer logs may be generated in this way so that tracer logs are available for a variety of different stimulation efficiencies. In order to determine the efficiency of an actual stimulation, the real tracer log of the stimulated well may be compared to the synthetic tracer logs in search of a match. When the real tracer log matches a synthetic tracer log the modeled efficiency of the synthetic log may be used as the actual or true efficiency of the real well stimulation.

Systems and methods for evaluating and optimizing stimulation efficiency using diverters

Systems and methods for analyzing and designing a customized pulse fracturing operation for fracturing a wellbore in a reservoir formation are disclosed. Pulsed fracturing can create multiple fractures that radiate away from the wellbore while minimizing near wellbore damage. This network can further be extended into the reservoir by utilizing an optimized pumping rate over a predetermined amount of time. The optimized pulse rate and duration can be determined by using a geomechanical and a reservoir simulator which can help in quantifying the production efficiency of the induced fracture network.

System and method for modeling and design of pulse fracturing networks

Systems and methods generate optimized formation fracturing operational parameters by iteratively optimizing bottom hole temperature design, perforation design, fracturing fluid pulse design, and proppant design based on formation properties, proppant properties, candidate selection, flow and geomechanical modeling, and engineering design, where the systems and methods as implemented on a digital processing unit.

Systems and methods for optimizing formation fracturing operations

Growing community of inventors

Houston, TX, United States of America

Jian Huang