Schlumberger Technology Corporation

Romain Charles Andre Prioul

Andrew Emil Pomerantz

Ridvan Akkurt

Florian Karpfinger

Brice Lecampion

Oliver Clinton Mullins

Bikash Kumar Sinha

Henri-Pierre Valero

Xiaowei Weng

Douglas E Miller

Denis Heliot

George Alan Waters

Erik Wielemaker

Ahmad Latifzai

Andreas Hausot

Bruce A MacKay

Jeroen Jocker

Canyun Wang

Thomas Berard

Alireza Farahani

Gong Rui Yan

Alexander Ramirez

Maurizio Ferla

Ferdinanda Pampuri

Dimitry Chuprakov

Andrey Bakulin

Chang Liu

Walid Ben-Ismail

Embodiments herein relate to a method for hydraulic fracturing a subterranean formation traversed by a wellbore including characterizing the formation using measured properties of the formation, including mechanical properties of geological interfaces, identifying a formation fracture height wherein the identifying comprises calculating a contact of a hydraulic fracture surface with geological interfaces, and fracturing the formation wherein a fluid viscosity or a fluid flow rate or both are selected using the calculating. Embodiments herein also relate to a method for hydraulic fracturing a subterranean formation traversed by a wellbore including measuring the formation comprising mechanical properties of geological interfaces, characterizing the formation using the measurements, calculating a formation fracture height using the formation characterization, calculating an optimum fracture height using the measurements, and comparing the optimum fracture height to the formation fracture height.

Method for improved design of hydraulic fracture height in a subterranean laminated rock formation

An apparatus and methods for forming a transverse fracture in a subterranean formation surrounding a wellbore including measuring a property along the length of the formation surrounding the wellbore, forming a stress profile of the formation, identifying a region of the formation to remove using the stress profile, removing the region with a device in the wellbore, and introducing a fluid into the wellbore, wherein a transverse fracture is more likely to form than if the region was not removed. Some embodiments benefit from computing the energy required to initiate and propagate a fracture from the region, optimizing the fluid introduction to minimize the energy required, and optimizing the geometry of the region.

Competition between transverse and axial hydraulic fractures in horizontal well

A method can include receiving data that characterizes anisotropy of a formation; receiving a model that models one or more planes of weakness in an anisotropic formation; and, based at least in part on the model and the data, outputting information germane to stability of a bore in an anisotropic formation.

Formation stability modeling

Embodiments herein relate to a method for recovering hydrocarbons from a formation including collecting and analyzing a formation sample, drilling operation data, and wellbore pressure measurement, estimating a reservoir and completion quality, and performing an oil field service in a region of the formation comprising the quality. In some embodiments, the formation sample is a solid collected from the drilling operation or includes cuttings or a core sample.

Reservoir and completion quality assessment in unconventional (shale gas) wells without logs or core

A computer-implemented method for determining elastic properties for a heterogeneous anisotropic geological formation is described herein. The method includes grouping sonic velocity data from a borehole section (or borehole sections) into a number of clusters (e.g., one or more clusters). The sonic velocity data is grouped into clusters using petrophysical log data from the borehole section. The method also includes inverting the sonic velocity data for the clusters to determine elastic properties for each cluster. In some cases, the elastic properties for the clusters are combined to determine a relationship between the elastic properties and formation heterogeneity.

Method to characterize heterogeneous anisotropic media

Methods and related systems are described for measuring acoustic signals in a borehole during a fracturing operation. The system includes a downhole toolstring designed and adapted for deployment in a borehole formed within a subterranean rock formation. A downhole rock fracturing tool opens and propagates a fracture in the subterranean rock formation. Dipole and/or quadrupole acoustic sources transmit acoustic energy into the subterranean rock formation. A receiver array measures acoustic energy traveling through the subterranean rock formation before, during and after the fracture induction. Geophones mounted on extendable arms can be used to measure shear wave acoustic energy travelling in the rock formation. The toolstring can be constructed such that the sources and receivers straddle the fracture zone during the fracturing. Alternatively, the sources or the receivers can co-located axially with the fracture zone, or the toolstring can be repositioned following fracturing such that the fracture zone is between the acoustic sources and receivers.

Microhydraulic fracturing with downhole acoustic measurement

The subject disclosure relates to determining an optimum orientation for perforations around the circumference of a subsurface borehole and optimum wellbore fluid initiation pressure for hydraulic fracturing in anisotropic formations.

Method to optimize perforations for hydraulic fracturing in anisotropic earth formations

A method and system is described for estimating stress characteristics from seismic data. The method includes receiving seismic data acquired over a region, receiving properties of rock at a location within the region, and estimating one or more stress characteristics for a sub-region by combining the seismic data and the rock properties using a relationship between the stress characteristics in the sub-region and elastic stiffness and/or sonic velocity in the sub-region. The relationship is based on a non-linear elasticity theory. The described system and method also includes analyzing in the seismic data azimuth and offset dependence of seismic signatures for seismic anisotropy thereby determining a set of anisotropic coefficients; identifying directions of minimum, intermediate and maximum stresses from orientation of principal axes of seismic anisotropy and signs of the anisotropic coefficients; and inverting the anisotropic coefficients thereby estimating magnitudes of principal stresses in the sub-region using non-linear elastic constants and vertical total stress information derived from the rock properties.

System and method for estimating subsurface principal stresses from seismic reflection data

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Somerville, MA, United States of America

Romain Charles Andre Prioul