The present disclosure is directed to articles that include a cured coating that includes a matrix of crosslinked polymers and optionally a colorant (e.g., pigment particles or dye or both). The cured coating can include a matrix of crosslinked polymers. The cured coating is a product of crosslinking a coating composition comprising uncrosslinked polymers (e.g., a dispersion of uncrosslinked polymers in a carrier to form the matrix of crosslinked polymers), wherein the uncrosslinked polymers are crosslinked to form the matrix of crosslinked polymers. The matrix of crosslinked polymers can be elastomeric. The present disclosure is also directed to articles including these bladders, methods of forming these bladders, and methods of making articles including these bladders, where the bladders include the cured coating.

Examples of the present disclosure relate to systems and methods for mapping a wellbore for refracturing. More specifically, embodiments are directed towards utilizing downhole pressure data to identify previously untreated clusters, clusters with cross contamination, and clusters with proper zonal isolation with full pressure integrity.

A fluid sampling tool and method for fluid sampling in an ultra-tight or tight formation. The tool may include a packer assembly that includes one or more inflatable packers and one or more exhaust ports, a multi-chamber section that includes one or more sample chambers, and at least two storage sections that each contain a storage tank, wherein each storage tank holds a stimulation fluid. A method for performing a stimulation operation that includes disposing a fluid sampling tool into a well, moving the fluid sampling tool to a zone of interest, and isolating the zone of interest with a packer assembly on the fluid sampling tool. The method may further include performing a first pressure draw down and a first pressure build up, performing an injectivity test, and performing a sampling process.

Systems, methods, and apparatus for determining permeability of subsurface formations are provided. In one aspect, a method includes: positioning a sample of the subsurface formation in a measurement cell, fluidly connecting an inlet and an outlet of the sample to an upstream reservoir and a downstream reservoir, respectively, flowing a fluid through the sample from the upstream reservoir to the downstream reservoir, measuring changes of an upstream pressure associated with the upstream reservoir and a downstream pressure associated with the downstream reservoir in a measurement time period, and determining a matrix permeability of the subsurface formation based on measurement data before the upstream pressure and the downstream pressure merge at a merging time point.

A test tool attached to test string comprising a fluid conduit is deployed to a test position within a wellbore. The deployment includes hydraulically isolating a portion of the wellbore proximate the test tool to form an isolation zone containing the test position. A fluid inflow test is performed within the isolation zone and an initial formation property and a fluid property are determined based on the fluid inflow test. A fluid injection test is performed within the isolation zone including applying an injection fluid through the test string into the isolation zone, wherein the flow rate or pressure of the injection fluid application is determined based, at least in part, on the at least one of the formation property and fluid property.

A method includes positioning a formation tester tool into a borehole formed within a formation and radially expanding a first and second radially extendable packers of the formation tester tool out from the formation tester tool to the formation to form a sealed volume between the first radially extendable packer and the second radially extendable packer. The method includes radially extending a pad of the formation tester tool that is positioned between the first radially extendable packer and the second radially extendable packer to form a sealed connection volume between the formation and a pressure sensor within the pad. The method includes acquiring a first pressure measurement, using the pressure sensor, from fluids in the sealed connection volume and extracting fluid from the sealed volume to reduce pressure around the pad. The method includes acquiring a second pressure measurement, using the pressure sensor, from fluids in the sealed connection volume.

A downhole tool designed to be disposed in a borehole of a subterranean formation is provided. The downhole tool includes a probe used to interface with the subterranean formation in order to sample fluid from or to inject fluid into the subterranean formation. The downhole tool also includes a sample flowline fluidly coupled to the probe and used to direct fluid through the downhole tool. The downhole tool further includes at least two volume chambers. These volume chambers each include a first side fluidly coupled to the sample flowline, a second side fluidly coupled to the guard flowline, and a piston separating the first side from the second side. The downhole tool is able to control a flow of fluid from a high pressure environment to a low pressure environment via the at least two volume chambers, the sample flowline, and the guard flowline.

A method comprises measuring a first external pressure within an annulus formed between a wellbore and a drill string disposed therein, where the first external pressure is measured by a first external pressure sensor. A fluid is pumped through the drill string into the annulus so as to move any cuttings in the annulus above the first external pressure sensor. A first internal pressure is measured within the drill string by a first internal pressure sensor. The first external pressure sensor is disposed between the first internal pressure sensor and a bottom of the wellbore.

Example methods and systems are described for automatic pumping control for a leak-off test (LOT) of a subterranean region. In some aspects, injection fluid is flowed into a closed wellbore in a subterranean region. Wellbore pressure in response to flowing the injection fluid into the closed wellbore is measured. A plot representing a wellbore pressure in response to cumulative injection fluid volumes is substantially linear is determined. After determining the plot is linear, a first injection fluid pressure measured in response to flowing the injection fluid deviates from the substantially linear plot by a first variance greater than a threshold variance is determined. A second injection fluid pressure measured in response to flowing the injection fluid deviates from the substantially linear plot by a second variance greater than the threshold variance is determined. In response to the above two determinations, flow of injection fluid into the closed wellbore is stopped.

A method for treating a well includes hydraulically isolating an interval in a first well having a plurality of intervals along the first well, each interval having been fracture treated. A tube wave is induced in the first well in the isolated interval. Reflections are detected from the induced tube wave. Hydraulic boundary condition and hydraulic conductivity of a fracture connected to the first well in the isolated interval are determined using the detected reflections. A refracture treatment is performed in the isolated interval when the hydraulic boundary condition and the hydraulic conductivity are within a predetermine range.