Abstract: In an embodiment, a method for forming a solder bump includes preparing a transfer mold having a solder pillar extending from a mold substrate and through a first photoresist layer and having a shape partially defined by a second photoresist layer that is removed prior to transfer of the solder. In an embodiment, the mold substrate is flexible. In an embodiment, the transfer mold is flexible. In an embodiment, the method includes providing a device substrate having a wettable pad. In an embodiment, the method includes placing the transfer mold and the device substrate into aligned contact such that the solder pillar is in contact with the wettable pad. In an embodiment, the method includes forming a metallic bond between the solder pillar and the wettable pad. In an embodiment, the method includes removing the mold substrate and first photoresist layer.

Abstract: A method for detecting wellbore inflows can include detecting a plurality of temperature values within a wellbore, wherein each temperature value corresponds to a different depth within the wellbore and the temperature values are detected with a distributed temperature measuring technique. The method can also include calculating a plurality of proxy temperatures, wherein each proxy temperature corresponds to one of the temperature values and a reference temperature value. The method can also include calculating a continuous wavelet transform based on the plurality of proxy temperatures. Additionally, the method can include identifying a wellbore inflow based on a combination of the continuous wavelet transform and a wellbore schematic, and generating an alert indicating a location of the wellbore inflow within the wellbore.

Abstract: Herein disclosed are methods and systems related to processes for injection wells generally utilized in the oil and gas industry. More particularly, disclosed herein are methods and systems related to improving the accuracy of profiling and determining individual cumulative fluid injection profiles for an injection period for multiple zones of an injection well in reservoir systems utilizing conventional warmback models. The methods herein allow for proper modeling and allocation of all injection zones, including zones experiencing a cooldown phenomena during shut-in by transforming the cooldown zonal temperature profiles into temperature profiles which can be utilized in a conventional warmback analysis. These methods are particularly useful in mature reservoir systems where the background reference temperature profile is no longer governed by the geothermal reference temperature profile.

Abstract: Herein disclosed are methods and systems related to processes for injection wells generally utilized in the oil and gas industry. More particularly, disclosed herein are methods and systems related to improving the accuracy of profiling and determining individual cumulative fluid injection profiles for an injection period for multiple zones of an injection well in reservoir systems utilizing conventional warmback models. The methods herein allow for proper modeling and allocation of all injection zones, including zones experiencing a cooldown phenomena during shut-in by transforming the cooldown zonal temperature profiles into temperature profiles which can be utilized in a conventional warmback analysis. These methods are particularly useful in mature reservoir systems where the background reference temperature profile is no longer governed by the geothermal reference temperature profile.

Abstract: A method for detecting wellbore inflows can include detecting a plurality of temperature values within a wellbore, wherein each temperature value corresponds to a different depth within the wellbore and the temperature values are detected with a distributed temperature measuring technique. The method can also include calculating a plurality of proxy temperatures, wherein each proxy temperature corresponds to one of the temperature values and a reference temperature value. The method can also include calculating a continuous wavelet transform based on the plurality of proxy temperatures. Additionally, the method can include identifying a wellbore inflow based on a combination of the continuous wavelet transform and a wellbore schematic, and generating an alert indicating a location of the wellbore inflow within the wellbore.

Abstract: A computer-implemented method for automated rock physics modeling. The method includes the steps of (a) pre-processing data obtained from a suite of logging tools over a range of depths; (b) using an automated, computer-implemented procedure to determine a solution to an inverse problem associated with the rock physics model using the data from step (a), the solution including a list of optimal parameters; (c) performing a forward run of the rock physics model; and (d) computing a set of rock mechanical properties using the optimal parameters obtained in step (b). A computer program product for automated rock physics modeling is also provided.

Abstract: A computer-implemented method for automated rock physics modeling. The method includes the steps of (a) pre-processing data obtained from a suite of logging tools over a range of depths; (b) using an automated, computer-implemented procedure to determine a solution to an inverse problem associated with the rock physics model using the data from step (a), the solution including a list of optimal parameters; (c) performing a forward run of the rock physics model; and (d) computing a set of rock mechanical properties using the optimal parameters obtained in step (b). A computer program product for automated rock physics modeling is also provided.

Abstract: A method for hydrocarbon management of a reservoir is provided. The method includes generating a model of a reservoir comprising a plurality of homogenized mixed finite elements in an unstructured computational mesh. The unstructured computational mesh may be coarsened to form a plurality of coarser computational meshes in the model. A convection-diffusion subsurface process may be evaluated on a coarsest computation mesh. A result may be transferred from the coarsest computational mesh to a finest computational mesh, and a performance parameter for the hydrocarbon reservoir may be predicted from the model. The predicted performance parameter may be used for hydrocarbon management of the reservoir.