Abstract: A method of attenuating annular pressure buildup within a wellbore. The method includes running first and second strings of casing into a wellbore, wherein the first string of casing surrounds an upper portion of the second string of casing forming an annular region. The method also includes providing a packing of compressible material within the annular region. The compressible material comprises carbonaceous particles. The particles may reside within a porous sleeve or filter, or they may be packed together in a matrix using a cross-linked polymer or binder. The packing is fixed at a selected depth within the annular region, and is designed so that the compressible material absorbs pressure in response to thermal expansion of wellbore fluids during the production of hydrocarbon fluids from the wellbore. The method further includes placing a wellhead over the wellbore, thereby forming a trapped annulus in the wellbore over the annular region.

Abstract: A method for determining propped fracture dimensions for a parent well includes hydraulic fracturing a stage of a child well to form a child well fracture, as well as, during the hydraulic fracturing process, measuring, via the parent well, data that are indicative of the formation of a hydraulic connection between the wells via interaction between the wetted front of the child well fracture and the propped region of a corresponding parent well fracture. The method includes measuring TFR (or VFR) data corresponding to the formation of the hydraulic connection between the two wells. The method includes estimating a child well fracture dimension when the hydraulic connection was formed using the TFR data, in combination with a fracture growth profile, and estimating a propped fracture dimension of the parent well fracture based on the estimated dimension of the child well fracture and the distance between the wells at that stage.

Abstract: A method for controlling the growth of a hydraulic fracture using a stress shadow generated during a hydraulic fracturing operation includes selecting a stage pair including a first stage and a second stage for which hydraulic fractures are to be generated via a hydraulic fracturing operation. The method also includes hydraulic fracturing the first stage to generate a corresponding first hydraulic fracture and controlling a magnitude of a stress shadow originating from the first hydraulic fracture by varying at least one parameter of the hydraulic fracturing operation, where the stress shadow is controlled so as to provide a second hydraulic fracture of a target fracture shape for the second stage. The method further includes hydraulic fracturing the second stage to generate the second hydraulic fracture with the target fracture shape.

Abstract: A method for controlling the growth of a hydraulic fracture using a stress shadow generated during a hydraulic fracturing operation includes selecting a stage pair including a first stage and a second stage for which hydraulic fractures are to be generated via a hydraulic fracturing operation. The method also includes hydraulic fracturing the first stage to generate a corresponding first hydraulic fracture and controlling a magnitude of a stress shadow originating from the first hydraulic fracture by varying at least one parameter of the hydraulic fracturing operation, where the stress shadow is controlled so as to provide a second hydraulic fracture of a target fracture shape for the second stage. The method further includes hydraulic fracturing the second stage to generate the second hydraulic fracture with the target fracture shape.

Abstract: A method for adjusting the treatment schedule for a hydraulic fracturing operation corresponding to a hydrocarbon well to limit one or more pumping parameters (e.g., the pump time, pump volume, and/or pump rate) includes analyzing fracture diagnostic data and/or fracture model data to estimate the pumping parameter(s) at which the maximum number of hydraulic fractures will approximate a target fracture dimension during the hydraulic fracturing operation. The method also includes adjusting the treatment schedule for the hydraulic fracturing operation based on the estimated pumping parameter(s) and then hydraulic fracturing the hydrocarbon well according to the adjusted treatment schedule.

Abstract: A method for determining propped fracture dimensions for a parent well includes hydraulic fracturing a stage of a child well to form a child well fracture, as well as, during the hydraulic fracturing process, measuring, via the parent well, data that are indicative of the formation of a hydraulic connection between the wells via interaction between the wetted front of the child well fracture and the propped region of a corresponding parent well fracture. The method includes measuring TFR (or VFR) data corresponding to the formation of the hydraulic connection between the two wells. The method includes estimating a child well fracture dimension when the hydraulic connection was formed using the TFR data, in combination with a fracture growth profile, and estimating a propped fracture dimension of the parent well fracture based on the estimated dimension of the child well fracture and the distance between the wells at that stage.

Abstract: A method of attenuating annular pressure buildup within a wellbore. The method includes running first and second strings of casing into a wellbore, wherein the first string of casing surrounds an upper portion of the second string of casing forming an annular region. The method also includes providing a packing of compressible material within the annular region. The compressible material comprises carbonaceous particles. The particles may reside within a porous sleeve or filter, or they may be packed together in a matrix using a cross-linked polymer or binder. The packing is fixed at a selected depth within the annular region, and is designed so that the compressible material absorbs pressure in response to thermal expansion of wellbore fluids during the production of hydrocarbon fluids from the wellbore. The method further includes placing a wellhead over the wellbore, thereby forming a trapped annulus in the wellbore over the annular region.

Abstract: A method of designing compressible particles for a fluid mixture. The compressible particles are intended to be used for attenuating pressure within a confined volume such as a trapped annulus. Preferably, the compressible particles reside buoyantly within an aqueous fluid, forming a fluid mixture. Each of the compressible particles is fabricated to collapse in response to fluid pressure within the confined volume, and comprises carbon. The particles may each have a porosity of between 5% and 40%, and a compressibility of between 10% and 30%, at 10,000 psi. The particles are tuned to have a buoyancy that is lower than the carrier fluid while still having resiliency.

Abstract: A fluid mixture for attenuating pressure within a confined volume. The fluid mixture comprises an aqueous carrier fluid. The fluid mixture further comprises a plurality of compressible particles dispersed in the carrier fluid. Each of the compressible particles is fabricated to collapse in response to fluid pressure within a confined volume. Each of the compressible particles has a density that is less than a density of the carrier fluid and has a compressibility of between 10% and 30%, up to 10,000 psi. A column of fluid within a trapped annulus of a wellbore is also presented, wherein the column of fluid has a plurality of compressible particles dispersed in a carrier fluid.

Abstract: A method of placing compressible particles within a wellbore. The method first comprises accessing a wellbore. The wellbore has a first string of casing and a second string of casing, wherein the first string of casing surrounds an upper portion of the second string of casing, forming a trapped annulus. The method further includes pumping a fluid mixture down the second string of casing and back up the annulus. The fluid mixture comprises an aqueous carrier fluid having a plurality of compressible particles dispersed therein. Each of the compressible particles is fabricated to collapse in response to fluid pressure within the trapped annulus. The method additionally includes pumping cement into at least a lower portion of the annulus behind the fluid mixture, forming a column of cement, and thereby placing the fluid mixture in the annulus above the column of cement.

Abstract: A collection of compressible particles. The compressible particles are intended to be used for attenuating pressure within a confined volume such as a trapped annulus. Preferably, the compressible particles buoyantly reside within an aqueous fluid, forming a fluid mixture. Each of the compressible particles is fabricated to collapse in response to fluid pressure within the confined volume, and comprises carbon. The particles may each have a porosity of between 5% and 40%, and a compressibility of between 10% and 30%, at up to 10,000 psi. Each of the particles has a resiliency of between 80% and 120%.

Abstract: A method of designing compressible particles for a fluid mixture. The compressible particles are intended to be used for attenuating pressure within a confined volume such as a trapped annulus. Preferably, the compressible particles reside buoyantly within an aqueous fluid, forming a fluid mixture. Each of the compressible particles is fabricated to collapse in response to fluid pressure within the confined volume, and comprises carbon. The particles may each have a porosity of between 5% and 40%, and a compressibility of between 10% and 30%, at 10,000 psi. The particles are tuned to have a buoyancy that is lower than the carrier fluid while still having resiliency.

Abstract: A method of placing compressible particles within a wellbore. The method first comprises accessing a wellbore. The wellbore has a first string of casing and a second string of casing, wherein the first string of casing surrounds an upper portion of the second string of casing, forming a trapped annulus. The method further includes pumping a fluid mixture down the second string of casing and back up the annulus. The fluid mixture comprises an aqueous carrier fluid having a plurality of compressible particles dispersed therein. Each of the compressible particles is fabricated to collapse in response to fluid pressure within the trapped annulus. The method additionally includes pumping cement into at least a lower portion of the annulus behind the fluid mixture, forming a column of cement, and thereby placing the fluid mixture in the annulus above the column of cement.

Abstract: A fluid mixture for attenuating pressure within a confined volume. The fluid mixture comprises an aqueous carrier fluid. The fluid mixture further comprises a plurality of compressible particles dispersed in the carrier fluid. Each of the compressible particles is fabricated to collapse in response to fluid pressure within a confined volume. Each of the compressible particles has a density that is less than a density of the carrier fluid and has a compressibility of between 10% and 30%, up to 10,000 psi. A column of fluid within a trapped annulus of a wellbore is also presented, wherein the column of fluid has a plurality of compressible particles dispersed in a carrier fluid.

Abstract: A tubular body for a wellbore. The tubular body comprises an elongated pipe body having a box end and a pin end, defining a wall. The tubular body includes a filter screen. The filter screen is disposed around an outer diameter of the wall along at least a portion of the elongated body. The filter screen defines a cylindrical body having slots there along. A plurality of compressible particles are held within the filter screen. Each of the compressible particles is fabricated to collapse in response to fluid pressure communicated through the slots. A method of mitigating pressure within a trapped annulus is also provided herein. The method includes the use of at least one of the tubular bodies along a casing string.

Abstract: A collection of compressible particles. The compressible particles are intended to be used for attenuating pressure within a confined volume such as a trapped annulus. Preferably, the compressible particles buoyantly reside within an aqueous fluid, forming a fluid mixture. Each of the compressible particles is fabricated to collapse in response to fluid pressure within the confined volume, and comprises carbon. The particles may each have a porosity of between 5% and 40%, and a compressibility of between 10% and 30%, at up to 10,000 psi. Each of the particles has a resiliency of between 80% and 120%.