Abstract: A system and method is provided for performing stimulation operations at a wellsite having a subterranean formation with a reservoir therein. The method involves acquiring integrated wellsite data (e.g., geomechanical, geological, and/or geophysical properties of the formation, and/or geometrical properties of the mechanical discontinuities in the formation). The method also involves generating a mechanical earth model using the integrated wellsite data, and identifying a crossing behavior between an induced hydraulic fracture and at least one discontinuity in the formation. The method also involves optimizing a stimulation plan to achieve an optimized crossing behavior. The stimulation plan includes at least one of fluid viscosity, rate of injection of the fracturing fluid, and concentration of a fluid loss additive. The optimization may further include adjusting the stimulation plan to achieve the optimized crossing behavior between the induced hydraulic fracture and the discontinuity in the formation.

Abstract: A system and method for performing stimulation operations at a wellsite having a subterranean formation with of a reservoir therein is provided. The method involves generating a plurality of quality indicators from a plurality of logs, and combining the plurality of quality indicators to form a composite quality indicator. The plurality of stress blocks may then be merged using diversion criterion. The composite quality indicator may be combined with the merged stress blocks to form a combined stress and composite quality indicator, the combined stress and composite quality indicator comprising a plurality of blocks with boundaries therebetween. The method may further comprise defining stages along the combined stress and composite quality indicator based on the diverter-assisted stage classifications; and selectively positioning perforations in select stages based on the diverter-assisted stage classifications thereon.

Abstract: A method for determining flow distribution in a formation having a wellbore formed therein includes the steps of positioning a sensor within the wellbore, wherein the sensor generates a feedback signal representing at least one of a temperature and a pressure measured by the sensor, injecting a fluid into the wellbore and into at least a portion of the formation adjacent the sensor, shutting-in the wellbore for a pre-determined shut-in period, generating a simulated model representing at least one of simulated temperature characteristics and simulated pressure characteristics of the formation during the shut-in period, generating a data model representing at least one of actual temperature characteristics and actual pressure characteristics of the formation during the shut-in period, wherein the data model is derived from the feedback signal, comparing the data model to the simulated model, and adjusting parameters of the simulated model to substantially match the data model.

Abstract: A method of performing an oilfield operation about a wellbore penetrating a subterranean formation are provided. The method involves performing a fracture operation by generating fractures about the wellbore. The fractures define a hydraulic fracture network (HFN) about the wellbore. The method also involves generating a discrete fracture network (DFN) about the wellbore by extrapolating fracture data from the HFN. The DFN includes fracture branches with intersections therebetween and matrix blocks. The method also involves generating a depth of drainage through the DFN, defining production parameter(s), and performing a production operation to produce fluids from the subterranean formation based on the depth of drainage and the production parameter(s). The production operation may involve generating a flow rate through the DFN, generating a pressure profile of the DFN for an initial time based on the flow rate, and generating a production rate based on the pressure profile.

Abstract: A hydraulic fracture design model that simulates the complex physical process of fracture propagation in the earth driven by the injected fluid through a wellbore. An objective in the model is to adhere with the laws of physics governing the surface deformation of the created fracture subjected to the fluid pressure, the fluid flow in the gap formed by the opposing fracture surfaces, the propagation of the fracture front, the transport of the proppant in the fracture carried by the fluid, and the leakoff of the fracturing fluid into the permeable rock. The models used in accordance with methods of the invention are typically based on the assumptions and the mathematical equations for the conventional 2D or P3D models, and further take into account the network of jointed fracture segments. For each fracture segment, the mathematical equations governing the fracture deformation and fluid flow apply.

Abstract: A system and method of performing a microseismic fracture operation for a wellsite having a subterranean formation with a complex fracture network therein are provided. The method involves describing a relationship between microseismic events to determine the complex fracture network of the subterranean formation, generating a fault volume by extracting faults from the fracture network based on the relationship between the microseismic events, generating a discrete fracture network comprising discrete fractures from the complex fracture network by extracting fracture planes from the obtained fault volume, and simulating fracture geometry and proppant placement.

Abstract: The invention discloses a method of treating a subterranean formation of a well bore, that provides a first treatment fluid; subsequently, pumps the first treatment fluid to initiate a network of low conductivity fractures in the subterranean formation; provides a second treatment fluid comprising a second carrier fluid, a particulate blend including a first amount of particulates having a first average particle size between about 100 and 2000 ?m and a second amount of particulates having a second average particle size between about three and twenty times smaller than the first average particle size, such that a packed volume fraction of the particulate blend exceeds 0.74; and subsequently, pumps the second treatment fluid to initiate at least one high conductivity fracture in the subterranean formation, wherein the high conductivity fracture has a conductivity higher than the average of the conductivity of the low conductivity fractures and connects the network of the low conductivity fractures.

Abstract: A method is provided for performing a fracture treatment on a subterranean formation. The method includes acquiring subterranean formation layer geomechanical properties, which include well completion and reservoir data for the subterranean formation. The method also includes inputting geomechanical properties of the formation into a model, and simulating propagation of a network of fractures in the formation. The method further includes predicting a flow rate and pressure distribution throughout the network of fractures by solving governing deformation and flow equations, and predicting a result of the fracture treatment. The model is adjusted if the predicted result is not satisfactory.

Abstract: The invention discloses a method for use in a wellbore, comprising: providing a first fluid comprising at least a first type of particulate material having a first average particle size and a second type of particulate material having a second average particle size, wherein first average particle size is smaller than second average particle size; providing a second fluid comprising at least a third type of particulate material having a third average particle size and a fourth type of particulate material having a fourth average particle size, wherein third average particle size is smaller than fourth average particle size; and introducing the first fluid into the wellbore subsequently followed by introducing the second fluid into the wellbore, wherein the third average particle size is substantially equal to the second average particle size.

Abstract: An example apparatus includes a formation description module that interprets a formation description corresponding to a formation of interest, a fluid description module that interprets a high solids content fluid (HSCF) description, and a fracture modeling module that models a fracturing operation in the formation of interest in response to the formation description and the HSCF description. The apparatus further includes a fracture results module that provides a fracture treatment description parameter in response to the model.

Abstract: A hydraulic fracture design model that simulates the complex physical process of fracture propagation in the earth driven by the injected fluid through a wellbore. An objective in the model is to adhere with the laws of physics governing the surface deformation of the created fracture subjected to the fluid pressure, the fluid flow in the gap formed by the opposing fracture surfaces, the propagation of the fracture front, the transport of the proppant in the fracture carried by the fluid, and the leakoff of the fracturing fluid into the permeable rock. The models used in accordance with methods of the invention are typically based on the assumptions and the mathematical equations for the conventional 2D or P3D models, and further take into account the network of jointed fracture segments. For each fracture segment, the mathematical equations governing the fracture deformation and fluid flow apply.

Abstract: A method is provided for performing a fracture treatment on a subterranean formation. The method includes acquiring subterranean formation layer geomechanical properties, which include well completion and reservoir data for the subterranean formation. The method also includes inputting geomechanical properties of the formation into a model, and simulating propagation of a network of fractures in the formation. The method further includes predicting a flow rate and pressure distribution throughout the network of fractures by solving governing deformation and flow equations, and predicting a result of the fracture treatment. The model is adjusted if the predicted result is not satisfactory.

Abstract: An apparatus, system, and method are provided for determining injected fluid vertical placement in a formation. The apparatus includes a borehole drilled through a formation, and an injection conduit within the borehole. In one embodiment, the apparatus includes a fiber optic cable within the borehole wrapped helically around the injection conduit such that the fiber optic cable reads temperatures at specific depths and radial angles throughout the borehole. The apparatus includes a thermal insulation layer interposed between the injection conduit and the fiber optic cable such that the fiber optic cable detects the formation temperature rather than the injection conduit temperature. The apparatus includes a computer programmed to determine the vertical placement of the injected fluid within the formation based on the temperature readings. The apparatus detects an induced hydraulic fracture height, and detects whether an induced hydraulic fracture has deviated from the plane of the borehole.

Abstract: A system and method for performing stimulation operations at a wellsite having a subterranean formation with of a reservoir therein is provided. The method involves generating a plurality of quality indicators from a plurality of logs, and combining the plurality of quality indicators to form a composite quality indicator. The composite quality indicator may be combined with a stress log to form a combined stress and composite quality indicator, the combined stress and composite quality indicator comprising a plurality of blocks with boundaries therebetween. The method may further comprise identifying classifications for the plurality of blocks; defining stages along the combined stress and composite quality indicator based on the classifications; and selectively positioning perforations in select stages based on the classifications thereon.

Abstract: A system and method for performing stimulation operations at a wellsite having a subterranean formation with of a reservoir therein is provided. The method involves performing reservoir characterization to generate a mechanical earth model based on integrated petrophysical, geomechanical and geophysical data. The method also involves generating a stimulation plan by performing well planning, a staging design, a stimulation design and a production prediction based on the mechanical earth model. The stimulation design is optimized by repeating the well planning, staging design, stimulation design, and production prediction in a feedback loop until an optimized stimulation plan is generated.

Abstract: Methods and apparatus for using a fluid within a subterranean formation comprising forming a fluid comprising a fluid additive, introducing the fluid to a formation, observing a temperature, and controlling a rate of fluid introduction using the observed temperature, wherein the observed temperature is lower than if no observing and controlling occurred. A method and apparatus to deliver fluid to a subterranean formation comprising a pump configured to deliver fluid to a wellbore, a flow path configured to receive fluid from the pump, a bottom hole assembly comprising a fluid outlet and a temperature sensor and configured to receive fluid from the flow path, and a controller configured to accept information from the temperature sensor and to send a signal.

Abstract: The invention discloses a method of treating a subterranean formation of a well bore, that provides a first treatment fluid; subsequently, pumps the first treatment fluid to initiate a network of low conductivity fractures in the subterranean formation; provides a second treatment fluid comprising a second carrier fluid, a particulate blend including a first amount of particulates having a first average particle size between about 100 and 2000 ?m and a second amount of particulates having a second average particle size between about three and twenty times smaller than the first average particle size, such that a packed volume fraction of the particulate blend exceeds 0.74; and subsequently, pumps the second treatment fluid to initiate at least one high conductivity fracture in the subterranean formation, wherein the high conductivity fracture has a conductivity higher than the average of the conductivity of the low conductivity fractures and connects the network of the low conductivity fractures.

Abstract: A method for determining flow distribution in a formation having a wellbore formed therein includes the steps of positioning a sensor within the wellbore, wherein the sensor generates a feedback signal representing at least one of a temperature and a pressure measured by the sensor, injecting a fluid into the wellbore and into at least a portion of the formation adjacent the sensor, shutting-in the wellbore for a pre-determined shut-in period, generating a simulated model representing at least one of simulated temperature characteristics and simulated pressure characteristics of the formation during the shut-in period, generating a data model representing at least one of actual temperature characteristics and actual pressure characteristics of the formation during the shut-in period, wherein the data model is derived from the feedback signal, comparing the data model to the simulated model, and adjusting parameters of the simulated model to substantially match the data model.

Abstract: A method for determining characteristics of a tubing deployed in a wellbore includes positioning a first sensor within the wellbore, wherein the first sensor generates a first feedback signal representing a downhole parameter measured by the first sensor, positioning a second sensor adjacent a surface of the formation in which the wellbore is formed, wherein the second sensor generates a second feedback signal representing a surface parameter measured by the second sensor, generating a simulated model representing a simulated surface weight indicator of the tubing, wherein the simulated model is derived from at least the first feedback signal, generating a data model representing a measured weight indicator of the tubing, wherein the data model is derived from the second feedback signal, comparing the data model to the simulated model, and adjusting a parameter of the simulated model to substantially match the simulated model to the data model.

Abstract: Embodiments of this invention relate to a method for analysing data related to subterranean formations including collecting data from microseismic observations of a subterranean formation that is stored on a device, analysing the data using a tensor voting method, and providing an estimate of a surface of a subterranean formation. Embodiments of this invention relate to a method for analysing data related to subterranean formations including collecting data from microseismic observations of a subterranean formation, analysing the data using a tensor voting method, providing an estimate of a surface of a subterranean formation, and tailoring an aspect of an oil field service in response to the estimate.