Abstract: A method of fracturing a subsurface formation includes super-cooling liquid carbon dioxide to a temperature between ?60° F. to ?70° F. using liquid nitrogen having a temperature in a range of ?100° F. to ?200° F., pumping the lipid carbon dioxide down a wellbore to create fractures in the subsurface formation, and pumping fracturing fluid containing a proppant down the wellbore after pumping the liquid carbon dioxide down the wellbore.

Abstract: A system for cooling drilling fluid circulating in a wellbore drilled by a wellbore drilling system includes a drilling fluid conduit positioned at a surface location separate from a wellhead of the wellbore. Drilling fluid flowed from the wellbore and an outer jacket passes through the drilling fluid conduit. An inner surface of the outer jacket at least partially defines an interior volume within which the drilling fluid conduit is at least partially disposed. The interior volume is at least partially filled with liquid nitrogen, such that the drilling fluid passing through the drilling fluid conduit is cooled by heat exchange with the liquid nitrogen across a wall of the drilling fluid conduit prior to flowing back into the wellbore via a mud pump.

Abstract: A method of fracturing subsurface formation includes super-cooling water to a temperature between ?4° F. to ?30° F. using liquid nitrogen having a temperature in a range of ?100° F. to ?200° F., pumping the water down a wellbore to create fractures in the subsurface formation, and pumping fracturing fluid containing a proppant down the wellbore after pumping the water down the wellbore.

Abstract: A system for cooling drilling fluid circulating in a wellbore drilled by wellbore drilling system includes a drilling fluid conduit positioned at a surface location separate from a wellhead of the wellbore. Drilling fluid flowed from the wellbore and an outer jacket passes through the drilling fluid conduit. An inner surface of the outer jacket at least partially defines an interior volume within which the drilling fluid conduit is at least partially disposed. The interior volume is at least partially filled with liquid nitrogen, such that the drilling fluid passing through the drilling fluid conduit is cooled by heat exchange with the liquid nitrogen across a wall of the drilling fluid conduit prior to flowing back into the wellbore via a mud pump.

Abstract: A method to predict wireline caliper log data from logging-while-drilling data which includes collecting logging-while-drilling logs and caliper logs from a plurality of wells. The caliper log contains at least one channel. The method further includes pre-processing the logging-while-drilling data, selecting a subset of logs within the logging-while-drilling data, and aggregating the channels of the caliper logs forming aggregate logs. The method further includes splitting the pre-processed logging-while-drilling data and aggregate logs into train, validation, and test sets, wherein the validation and test sets may be the same, selecting a machine-learned model and architecture, and training the machine-learned model to form predicted aggregate logs from the logging-while-drilling data using the training set. Additionally, the method consists of using the machine-learned model to predict the aggregate logs using pre-processed logging-while-drilling data.

Abstract: A computer system obtains a first set of micro-computed tomography (micro-CT) data representing a rock sample obtained from a subterranean formation that includes gas-bearing sandstone. The system obtains a plurality of second sets of micro-CT data in a sequence, each representing the rock sample after a performance of a corresponding triaxial shear test on the rock sample. Performing each triaxial shear test includes applying a triaxial load force to the rock sample, and removing the triaxial load force from the rock sample. The system estimates, based on the first micro-CT data and the plurality of second sets of micro-CT data, one or more characteristics of the underground formation, including a permeability of the underground formation and/or a porosity of the underground formation. The system causes one or more resource extraction operations to be performed on the underground formation based on the one or more characteristics of the underground formation.

Abstract: Systems and methods include a method for determining a breakdown pressure for the wellbore. Input parameters are received for computing a breakdown pressure for a wellbore. A pore pressure is determined using a Stehfest method equation using a function of a time duration, a distance from the wellbore, an injection fluid compressibility, a Biot poroelastic parameter, and a modified Bessel function. A poroelastic stress is determined using a poroelastic stress equation based on the pore pressure determined for the wellbore, a Composite Simpson's Rule for numerical integration, an empirical parameter, a pore pressure, a Biot poroelastic parameter, tensile strength of rock, and a Poisson distribution. A breakdown pressure is determined using a tested time-based formula, poroelastic stress, a minimum and a maximum horizontal stress, using a formula tested against multiple wells and a distance from the wellbore in a radial direction.

Abstract: Systems and methods include a method for determining a breakdown pressure for the wellbore. Input parameters are received for computing a breakdown pressure for a wellbore. A pore pressure is determined using a Stehfest method equation using a function of a time duration, a distance from the wellbore, an injection fluid compressibility, a Biot poroelastic parameter, and a modified Bessel function. A poroelastic stress is determined using a poroelastic stress equation based on the pore pressure determined for the wellbore, a Composite Simpson's Rule for numerical integration, an empirical parameter, a pore pressure, a Biot poroelastic parameter, tensile strength of rock, and a Poisson distribution. A breakdown pressure is determined using a tested time-based formula, poroelastic stress, a minimum and a maximum horizontal stress, using a formula tested against multiple wells and a distance from the wellbore in a radial direction.

Abstract: A wellbore assembly includes a first tube and a second tube. The first tube is disposed within a wellbore and has a first end fixed with respect to a wall of the wellbore. The second tube is coupled to a second end of the first tube. The second tube has a third end opposite the coupling and fixed with respect to the wall of the wellbore. The first tube includes a portion of reduced or increased diameter residing between the first end and the second end. The portion of reduced or increased diameter defines an internal diameter that changes, with the first tube under a compression load, to decrease a length of the first tube. The internal diameter changes, with the first tube under a tensile load, to increase a length of the first tube to accommodate changes in length of the first tube or the second tube or both.