Abstract: Methods and related systems are described for use with hydraulic fracturing and other oilfield applications. A tool body is positioned in a wellbore at a location near a subterranean rock formation being fractured. The tool body contains a plurality of deployable continuous fibers. At least some of the deployable continuous fibers are deployed into fractures within a subterranean rock formation. Each deployed fiber is continuous from the tool body to the rock formation. The number of deployable continuous fibers provides sufficient redundancy to make at least a target measurement relating to the fracturing process.

Abstract: Methods and systems that utilize explosive and cryogenic means to establish fluid communication to areas away from the well bore walls are disclosed. A first fracture is induced in the subterranean formation. The first fracture is initiated at about a fracturing location and the initiation of the first fracture is characterized by a first orientation line. The first fracture temporarily alters a stress field in the subterranean formation. Explosives are then used to induce a second fracture in the subterranean formation. The second fracture is initiated at about the fracturing location and the initiation of the second fracture is characterized by a second orientation line. The first orientation line and the second orientation line have an angular disposition to each other.

Abstract: Radar ranging data are collected from a down hole tool at various depths in a fractured well bore, and analyzed to provide a profile of the length of each wing of the fracture as a function of depth. The height of the fracture is determined from the vertical positions where the fracture is just observed or no longer observed as the tool is raised or lowered. For consecutive depths along the fracture (and for selected elevations from each depth for the case of a switchable antenna beam), reflection intensity as a function of range is measured. Simulated radar data are computed from a fracture model having the height of the fracture begin measured. The fracture model is varied and the resulting simulated data are correlated with the survey data until a match of minimal error is determined.

Abstract: Provided are methods that include a method comprising: placing a clean fluid comprising proppant particulates into a portion of a fracture in a subterranean formation, and depositing one or more of the proppant particulates into the fracture to form a partial monolayer. In another aspect, the invention provides methods that include placing a degradable fluid loss additive comprising collagen into a subterranean formation.

Abstract: Performing a hydraulic fracture test includes conveying a downhole sub in a borehole to a formation, the downhole sub including a first sealing member, a second sealing member, and an extendable member disposed between the first sealing member and the second sealing member. The first sealing member and the second sealing member are actuated to define a first isolated zone within the borehole. A fluid is introduced to the borehole wall via the extendable member to fracture the formation whether extended or not, and a property of the formation is estimated at least in part using an output signal from a downhole transducer.

Abstract: The present invention involves a method and apparatus for enhanced recovery of petroleum fluids from the subsurface by injection of a steam and hydrocarbon vaporized solvent in contact with the oil sand formation and the heavy oil and bitumen in situ. Multiple propped hydraulic fractures are constructed from the well bore into the oil sand formation and filled with a highly permeable proppant. Steam, a hydrocarbon solvent, and a non-condensing diluent gas are injected into the well bore and the propped fractures. The injected gas flows upwards and outwards in the propped fractures contacting the oil sands and in situ bitumen on the vertical faces of the propped fractures. The steam condenses on the cool bitumen and thus heats the bitumen by conduction, while the hydrocarbon solvent vapors diffuse into the bitumen from the vertical faces of the propped fractures.

Abstract: A method of determining when to stop pumping proppant during hydraulic fracturing in a wellbore is described. By accurately detecting tip screen-out with a bottom hole pressure gauge mounted to a perforating gun, the optimal amount of proppant can be supplied to a fracture while avoiding the risks associated with wellbore screen-out.

Abstract: A method and apparatus for orchestrating multiple fractures at multiple well locations in a region by flowing well treatment fluid from a centralized well treatment fluid center is disclosed that includes the steps of configuring a well treatment fluid center for fracturing multiple wells, inducing a fracture at a first well location, measuring effects of stress fields from the first fracture, determining a time delay based in part upon the measured stress effects, inducing a second fracture after the time delay at a second location based upon the measured effects, and measuring the stress effects of stress fields from the second fracture. Sensors disposed about the region are adapted to output effects of the stress fields. Location and orientation of subsequent fractures is based on the combined stress effects of the stress fields as a result of the prior fractures which provides for optimal region development.

Abstract: An optical positioning monitoring system is disclosed. The system has an optical sensing member disposed on a wellbore pipe, such as the tubing or production casing. When a tool comprising an actuating member acts on the optical sensing member, an optical signal is returnable from the optical sensing member indicating the position of the tool. The optical sensing member may include an optical fiber and/or any known optical sensors. The actuating member can be a force applicator or a heat applicator. Alternatively, the optical sensing member can be located on the tool and the actuating member can be located on the tubing or production casing.

Abstract: Method to monitor reservoir fracture development and its geometry may find its application at oil and gas fields as well as in coal mining industry. The method provides injection of conductive fracturing fluid into the wellbore under pressure enabling to create a fracture in the formation and penetrate into it. At the stage corresponding to the end of the fracturing fluid charging a series of voltage pulses is applied to the fracturing fluid. In the well parameters of the electromagnetic field and/or acoustic signals resulting from applying the voltage pulses to the fracturing fluid are measured, and the fracture tip coordinates are determined.

Abstract: The invention is intended to determine the dimensions of the cracks resulting from the formation fracturing. To determine the crack dimensions a numerical model of the fracturing fluid ousting from the crack and filtrate zone with the formation fluid is made for the set formation parameters, fracturing data and supposed crack dimensions, the model is made to calculate the change of the fracturing fluid concentration in the total production during the well post-fracturing commissioning; during the well commissioning, throughout the entire fracturing fluid ousting period samples of the fluid produced are periodically taken from the well mouth and the fracturing fluid concentration in the samples taken is measure, then the measurement results are compared with the model calculations and the crack length is determined based on the best match of the measurement results and the model calculations.

Abstract: A process for hydrofracturing a specific interval or zone in a water aquifer from a water well borehole and introducing high-pressure water and gravel proppants for increasing water flow production from the water well. The process uses a hydrofracture tool having a perforated pipe section with a pair of inflatable packers. The tool is lowered into the borehole to the deepest interval to be fraced. The length of the tool is sufficient to span the width of the interval. The packers are then inflated thus sealing off the area in the borehole next to the interval. High-pressure water is then introduced through the drill stem and through ports in the perforated pipe section. After sufficient high-pressure water has fractured the surrounding interval, gravel proppants are forced into the surrounding fractured interval. Upon discontinuing the hydrofracturing of the interval, the two packers are deflated and the hydrofracture tool is moved upwardly to the next water-bearing interval and the process is repeated.

Abstract: A method, practiced by a Hydraulic Fracturing Simulator software, is adapted for simulating a hydraulic fracture in an Earth formation, the formation including a multilayered reservoir, a mesh adapted to overlay the fracture in the formation thereby defining a plurality of elements, the mesh and the fracture defining one or more partially active elements, the method comprising the step of: setting up an Influence Coefficient Matrix, the matrix having a plurality of numbers, the plurality of numbers of the Influence Coefficient Matrix being calculated and determined such that the method, practiced by the Hydraulic Fracturing Simulator software for simulating the hydraulic fracture, models, or take into account an existence of, the multilayered reservoir and the partially active elements.

Abstract: A system for monitoring a wellbore service treatment, comprising a downhole tool operable to perform the wellbore service treatment; a conveyance connected to the downhole tool for moving the downhole tool in the wellbore, and a plurality of sensors operable to provide one or more wellbore indications and attached to the downhole tool or a component thereof via one or more tethers. A method of monitoring a wellbore service treatment, comprising conveying into a wellbore a downhole tool operable to perform the wellbore service treatment and a plurality of sensors operable to provide one or more wellbore indications attached to the downhole tool or a component thereof via one or more tethers, deploying the downhole tool at a first position in the wellbore for service, treating the wellbore at the first position; and monitoring an at least one wellbore indication provided by the wellbore sensors at the first position.

Abstract: A method for lowering the temperature of a portion of a subsurface formation is provided. Preferably, the formation is an oil shale formation. The method includes the step of injecting a cooling fluid under pressure into a wellbore, with the wellbore having been completed at or below a depth of the subsurface formation. The wellbore has an elongated tubular member for receiving the cooling fluid and for conveying it downhole to the subsurface formation. The wellbore also has an expansion valve in fluid communication with the tubular member through which the cooling fluid flows. The method then includes the steps of injecting a cooling fluid under pressure into the wellbore, and expanding the cooling fluid across the first expansion valve. In this way, the temperature of the cooling fluid is reduced. The temperature of the surrounding formation is likewise reduced through thermal conduction and convection.

Abstract: New methods and systems for subterranean fracturing for hydrocarbon wells. A plan of the fracture propagation and in-fracture proppant distribution is used with a real-time model of the status of the fracture dimensions and in-fracture proppant concentration to automatically control flow rates and properties of a fracturing fluid flow stream being used to induce and prop the fracture. Real-time measurements of the status of the fracture are made using surface and/or down-hole sensors. Real-time control over the flow rate and properties of a fracturing fluid flow stream are made by manipulating the fracturing fluid supply equipment. Real-time modifications of the fracturing model are made by comparing fracture sensor measurements of actual fracture dimensions to the predicted dimensions, and then adjusting the model for inaccuracies. Real-time updates to the fracturing plan are made by comparing actual fracture and propping results to desired results, and then adjusting to achieve optimal results.

Abstract: A method for determining fracture geometry of a subterranean formation from radiation emitted from a fracture in the formation, including measuring gamma-radiation emitted from the fracture; subtracting background radiation from the measured gamma-radiation to obtain a peak-energy measurement; comparing the peak-energy measurement with a gamma-ray transport/spectrometer response model; and determining formation fracture geometry of the fracture in accordance with values associated with the response model.

Abstract: A pump monitoring system includes a monitoring device configured for attachment to a cable harness of a pump, a strain gauge configured to measure dynamic loading of at least one cable of the cable harness as the pump operates, a wireless transmitter configured to transmit the dynamic loading measurement, and an external device configured to receive the transmitted dynamic loading measurement.

Abstract: A method for stimulating production of a first wellbore associated with a reservoir. The method includes determining a textural complexity of a formation in which the reservoir is located, determining an induced fracture complexity of the formation using the textural complexity, determining a first operation to perform within the formation to maintain conductivity of the formation based on the induced fracture complexity and the textural complexity, performing the first operation within the formation, and fracturing the formation to create a first plurality of fractures.

Abstract: A method for stimulating production in a wellbore associated with a reservoir. The method includes determining a textural complexity of a formation in which the reservoir is located, determining an induced fracture complexity of the formation using the textural complexity, fracturing the formation to create a plurality of fractures, determining an operation to perform within the formation to maintain conductivity of the formation based on the induced fracture complexity and the textural complexity, and performing the operation, wherein the operation comprises drilling a lateral well originating from the wellbore to maintain conductivity of the formation.

Abstract: Methods that include a method of determining one or more approximate properties of a subterranean formation and/or a fracture therein comprising: obtaining fluid identity data for a plurality of flowback fluid samples; and using a reservoir model, with the fluid identity data and one or more subterranean formation properties as inputs thereto, to estimate one or more properties in a subterranean formation. Additional methods are provided.

Abstract: A method for hydraulic fracture imaging consistently integrates ground deformation data and microseismic data. A time sequence of hydraulic fracture images is computed from the combined data by first computing an orientation and location of the fracture. A size of the fracture (e.g., length, width, and opening) and detailed shape is then computed consistent with the computed orientation using a stochastic optimization procedure. This procedure may be performed by selecting a candidate model of the fracture consistent with the computed orientation, computing a predicted surface deformation from the candidate model (e.g., using elastic crack theory), computing a predicted seismic activity from the candidate model (e.g., using Dieterich seismicity rate theory), and comparing the predicted surface deformation and predicted seismic activity with the collected ground deformation data and earthquake locations derived from the collected seismic activity data.

Abstract: A system and a method for heterogeneous proppant placement in a fracture (12) in a subterranean formation (18) are disclosed. The system includes a delivery system (10) for delivering proppant and treatment fluid to the fracture (12), a sensor (20) for measuring geometry of the fracture and a computer (24) in communication with the sensor (20). The computer (24) includes a software tool for real-time design of a model (38) for heterogeneous proppant placement in the fracture (12) based on data from the sensor (20) measurements and a software tool for developing and updating a proppant placement schedule (42) for delivering the proppant and treatment fluid to the fracture (12) corresponding to the model. A control link between the computer (24) and the delivery system (10) permits the delivery system (10) to adjust the delivery of the proppant and treatment fluid according the updated proppant placement schedule.

Abstract: A method is provided for the reduction of inflow of rock particles from an earth formation into a wellbore for the production of hydrocarbon fluid. The method comprises creating a zone of reduced compressive stiffness around the wellbore by removing rock material from the wall of the wellbore.

Abstract: Methods of stabilizing unconsolidated portions of a subterranean formation are provided. In one embodiment, the methods comprise: creating or enhancing at least two slots in an unconsolidated portion of a subterranean formation along a well bore, wherein the slots are positioned about 180 degrees from each other along the inner surface of the well bore; introducing a consolidating agent into the slots in the unconsolidated portion of the subterranean formation; and creating or enhancing at least one fracture in a portion of the subterranean formation.

Abstract: A method for determining distribution data for a disposal domain parameter to increase assurance in a cuttings injection process, including performing a fracturing simulation using a site specific datum to obtain a fracturing result, determining a probability of creating a new fracture using the fracturing result and a probability model, performing a plurality of fracturing simulations using the probability and a distribution associated with the probability to obtain disposal domain information, and extracting the distribution data for the disposal domain parameter from the disposal domain information.

Abstract: An apparatus for testing a rheological property of a fluid with a particulate includes: (a) a receptacle having a cylindrical side wall enclosed by a bottom wall defining a cavity for receiving a fluid to be tested; (b) an axial support adapted to be positioned in the cavity of the receptacle, whereby relative rotational motion can be imparted to the receptacle and the axial support; (c) at least one inward projection extending inward from an inside surface of the receptacle; (d) at least one outward projection extending outward from the axial support; and (e) at least one projection for directing fluid flow that has at least one major surface angled or curved upward. A method of testing a rheological property of a fluid with a particulate includes: (a) placing a sample of the fluid and the particulate in the apparatus; (b) imparting relative rotational motion to the receptacle and the axial support; and (c) measuring the torque between the receptacle and the axial support.

Abstract: Disclosed herein is a method of determining the fracture geometry of a subterranean fracture comprising introducing into the fracture a target particle and/or proppant; transmitting into the fracture electromagnetic radiation having a frequency of about 300 megahertz to about 100 gigahertz; and analyzing a reflected signal from the target particle to determine fracture geometry. Disclosed herein too is a method of determining the fracture geometry of a subterranean fracture comprising introducing into the fracture a target particle and/or proppant; wherein the target particle and/or proppant comprises a high dielectric constant ceramic having a dielectric constant of greater than or equal to about 2; transmitting into the fracture electromagnetic radiation having a frequency of less than or equal to about 3 gigahertz; and analyzing a reflected signal from the target particle and/or proppant to determine fracture geometry.

Abstract: A method and apparatus for preventing erosion of a cable for use in a wellbore is described herein. The cable has one or more optical fibers adapted to monitor and/or control a condition in the wellbore. The cable includes a layer of elastomeric material at least partially located on an outer surface of the cable. The elastomeric material is adapted to absorb energy due to the impact of particles in production fluid or wellbore fluid against the cable.

Abstract: Prior to a hydraulic fracturing treatment, the estimated fracture length may be estimated with knowledge of certain physical properties of the proppant and transport fluid such as fluid viscosity, proppant size and specific gravity of the transport slurry as well as fracture geometry and the treatment injection rate. The estimated fracture length may be determined by the equation: (DPST)B=qi×(1/A)×CTRANS×(d2prop)×(1/?fluid)×(?SGPS) ??(I) wherein: DPST is thus the estimated propped fracture length; B is the exponent from the Power Law equation describing the transport slurry velocity vs. distance for the fracture geometry; qi is the injection rate per foot of injection height, bpm/ft.; and A is the multiplier from the Power Law equation describing the transport slurry velocity vs. distance for the fracture geometry; CTRANS, the transport coefficient, is the slope of the linear regression of the ISP vs. MHVST. dprop is the median proppant diameter, in mm.

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: New methods and systems for subterranean fracturing for hydrocarbon wells. A plan of the fracture propagation and in-fracture proppant distribution is used with a real-time model of the status of the fracture dimensions and in-fracture proppant concentration to automatically control flow rates and properties of a fracturing fluid flow stream being used to induce and prop the fracture. Real-time measurements of the status of the fracture are made using surface and/or down-hole sensors. Real-time control over the flow rate and properties of a fracturing fluid flow stream are made by manipulating the fracturing fluid supply equipment. Real-time modifications of the fracturing model are made by comparing fracture sensor measurements of actual fracture dimensions to the predicted dimensions, and then adjusting the model for inaccuracies. Real-time updates to the fracturing plan are made by comparing actual fracture and propping results to desired results, and then adjusting to achieve optimal results.

Abstract: A method and a system for accessing a target fluid in a formation of an oilfield are provided. The method involves acquiring physicochemical property information of a portion of the formation, determining a type and a concentration of a chemical agent based on the physicochemical property information of the portion of the formation, and applying the chemical agent at the portion of the formation to provide a chemical action, where the target fluid is released at the portion of the formation responding to the chemical action.

Abstract: An apparatus for testing a rheological property of a fluid with a particulate includes: (a) a receptacle having a cylindrical side wall enclosed by a bottom wall defining a cavity for receiving a fluid to be tested; (b) an axial support adapted to be positioned in the cavity of the receptacle, whereby relative rotational motion can be imparted to the receptacle and the axial support; (c) at least one inward projection extending inward from an inside surface of the receptacle; (d) at least one outward projection extending outward from the axial support; and (e) at least one projection for directing fluid flow that has at least one major surface angled or curved upward. A method of testing a rheological property of a fluid with a particulate includes: (a) placing a sample of the fluid and the particulate in the apparatus; (b) imparting relative rotational motion to the receptacle and the axial support; and (c) measuring the torque between the receptacle and the axial support.

Abstract: A method of characterizing the productivity of open hole gas well involves characterizing the chemical and/or isotopic composition of the gas contributing strata from a series of discrete samples by degassing the mud during drilling This data is then used to de-convolute the combined or mixed gas during well production after drilling is complete to determine the relative contributions of the now characterized strata.

Abstract: Methods that include a method of determining one or more approximate properties of a subterranean formation and/or a fracture therein comprising: obtaining fluid identity data for a plurality of flowback fluid samples; and using a reservoir model, with the fluid identity data and one or more subterranean formation properties as inputs thereto, to estimate one or more properties in a subterranean formation. Additional methods are provided.

Abstract: Solutions for the propagation of a hydraulic fracture in a permeable elastic rock and driven by injection of a Newtonian fluid. Through scaling, the dependence of the solution on the problem parameters is reduced to a small number of dimensionless parameters.

Abstract: The present invention relates to methods, systems, and apparatus for inducing fractures in a subterranean formation and more particularly to methods and apparatus to place a first fracture with a first orientation in a formation followed by a second fracture with a second angular orientation in the formation. The first and second fractures are initiated at about a fracturing location. The initiation of the first fracture is characterized by a first orientation line. The first fracture temporarily alters a stress field in the subterranean formation. The initiation of the second fracture is characterized by a second orientation line. The first orientation line and the second orientation line have an angular disposition to each other.

Abstract: Methods, systems, and apparatus for inducing fractures in a subterranean formation and more particularly methods and apparatus to place a first fracture with a first orientation in a formation followed by a second fracture with a second angular orientation in the formation are provided. First and second fractures are initiated at about a fracturing location. The initiation of the first fracture is characterized by a first orientation line. The first fracture temporarily alters a stress field in the subterranean formation. The initiation of the second fracture is characterized by a second orientation line. The first orientation line and the second orientation line have an angular disposition to each other.

Abstract: A formation fluid sampling tool is provided with reactants which are carried downhole and which are combined in order to generate heat energy which is applied to the formation adjacent the borehole. By applying heat energy to the formation, the formation fluids are heated, thereby increasing mobility, and fluid sampling is expedited.

Abstract: An oil and gas well assembly is provided that includes a wireline cable having at least one optical fiber; a downhole tool having at least one optical fiber; and a cablehead having a first end connected to the wireline cable, a second end connected to the downhole tool. The cablehead further includes at least one optical fiber which transmits data between the at least one downhole tool optical fiber and the at least one wireline cable optical fiber.

Abstract: A method for determining for a reservoir (1) containing fluids (W, O), the variation in the relative permeability (krO, krW) of at least one of the fluids, as a function of the saturation of at least one of the fluids (W, O),) is provided. According to this method a saturation distribution of one of the fluids of the reservoir is determined on the basis of a measurement of a physical property in the reservoir. A dynamic model (20) for the flow of fluids in the reservoir (1) is created. The dynamic model generates a saturation distribution. The saturation distribution (40) generated by the dynamic model is compared with saturation distribution obtained from measurement. The dynamic model (20) is updated with intermediate relative permeability values (krO)i and (krW)i and steps b and c are repeated if the saturation distribution generated by the dynamic model and that determined on the basis of measurement do not coincide.

Abstract: A hydraulic fracturing method is disclosed that includes designing a fracture treatment including a fluid pumping schedule to fracture a subterranean formation according to a design model that accounts for cumulative filter cake thickness, including polymer concentrated at the fracture surfaces, to provide a propped fracture width effectively greater than the cumulative filter cake thickness, and injecting fluids through a wellbore into the formation essentially according to the fluid pumping schedule of the fracture treatment design. A fracturing method is also disclosed that includes placing a high breaker loading in the filter cake. A composition is disclosed which comprises a fluid viscosified with a polymer and a fluid loss additive comprising a delayed breaker.

Abstract: Methods of improving the pressure containment integrity of subterranean well bores are provided. The methods include pumping a fracture sealing composition into the well bore that rapidly converts into a high friction pressure sealing composition which is impermeable, deformable, extremely viscous and does not bond to the faces of fractures. Thereafter, the fracture sealing composition is squeezed into one or more natural fractures or into one or more new fractures formed in the well bore to thereby increase the pressure containment integrity of the well bore. The methods also include the prediction of the expected increase in pressure containment integrity.

Abstract: Methods of improving the pressure containment integrity of subterranean well bores are provided. The methods include pumping a fracture sealing composition into the well bore that rapidly converts into a high friction pressure sealing composition which is impermeable, deformable, extremely viscous and does not bond to the faces of fractures. Thereafter, the fracture sealing composition is squeezed into one or more natural fractures or into one or more new fractures formed in the well bore to thereby increase the pressure containment integrity of the well bore. The methods also include the prediction of the expected increase in pressure containment integrity.

Abstract: Methods of improving the pressure containment integrity of subterranean well bores are provided. The methods include pumping a fracture sealing composition into the well bore that rapidly converts into a high friction pressure sealing composition which is impermeable, deformable, extremely viscous and does not bond to the faces of fractures. Thereafter, the fracture sealing composition is squeezed into one or more natural fractures or into one or more new fractures formed in the well bore to thereby increase the pressure containment integrity of the well bore. The methods also include the prediction of the expected increase in pressure containment integrity.

Abstract: The invention relates to monitoring of fluid-filled domains in various media including, for example, subterranean formations, construction elements, bones. Claimed are a method for determining characteristic sizes of a fluid-filled crack in a medium and a system for implementation thereof. In accordance with this method, oscillations of the fluid-filled crack are registered. Wave characteristics of standing interface waves propagating along the fluid-filled crack surfaces are determined based on the registered oscillations taking medium and fluid properties into account. The fluid-filled crack characteristic sizes are calculated based on the determined wave characteristics of the standing interface waves.

Abstract: A method and system for development of a naturally fractured formation may include generating a fracture model from a fracture treatment of a well in the naturally fractured formation. The fracture model may account for natural fractures in the naturally fractured formation. The fracture model may include the fracture volume of the fracture generated by the fracture treatment. Well spacing and fracture stimulation design for one or more wells in the naturally fractured formation may be determined based on the fracture model.

Abstract: A technique that is usable with a well includes deploying an assembly into a wellbore. The assembly includes at least one sensor. A fracturing fluid is injected under pressure into the wellbore to hydraulically fracture a subterranean formation of interest. The technique includes isolating the sensor from the fracturing and measuring acoustical energy that is generated by the hydraulic fracturing using the sensor(s).

Abstract: The present invention involves a method and apparatus for enhanced recovery of petroleum fluids from the subsurface by injection of a steam and hydrocarbon vaporized solvent in contact with the oil sand formation and the heavy oil and bitumen in situ. Multiple propped hydraulic fractures are constructed from the well bore into the oil sand formation and filled with a highly permeable proppant. Steam, a hydrocarbon solvent, and a non-condensing diluent gas are injected into the well bore and the propped fractures. The injected gas flows upwards and outwards in the propped fractures contacting the oil sands and in situ bitumen on the vertical faces of the propped fractures. The steam condenses on the cool bitumen and thus heats the bitumen by conduction, while the hydrocarbon solvent vapors diffuse into the bitumen from the vertical faces of the propped fractures.