A method for stimulating production of hydrocarbons from a sandstone formation includes the steps of injecting a stimulation fluid formed from a hydrofluoric acid generating precursor and an oxidizing agent, an ammonium containing compound, and a nitrite containing compound into the sandstone formation, where one or both of the hydrofluoric acid generating precursor and the oxidizing agent comprise a degradable encapsulation. The method further includes maintaining the stimulation fluid, the ammonium containing compound, and the nitrite containing compound in the sandstone formation to initiate reaction and generate heat and nitrogen gas. Upon generation of heat and degradation of the degradable encapsulation, the hydrofluoric acid generating precursor and the oxidizing agent react to form hydrofluoric acid in-situ to dissolve silica and silicate minerals and stimulate the sandstone formation. A treatment fluid for use in stimulating sandstone formations includes the stimulation fluid, the ammonium containing compound, and the nitrite containing compound.

A method may include obtaining power production and fuel consumption data of a first piece of rig equipment through a flow meter, where the rig equipment includes a plurality of pieces of equipment. The method further includes feeding the power production and fuel consumption data of the first piece of rig equipment into a real-time monitoring system of the rig via the flow meter. The method further includes determining an energy efficiency, based on real-time performance, of the first piece of rig equipment using a consumption efficiency model. The method further includes comparing the energy efficiency of the first piece of rig equipment against continuously updated historical data of the first piece of rig equipment by a real-time database monitoring system. The method further includes identifying deficiencies of the first piece of rig equipment in real-time and determining maintenance or replacement of the first piece of rig equipment.

A method for producing hydrocarbons within a reservoir includes (a) injecting an aqueous solution into the reservoir. The aqueous solution includes water and a thermally activated chemical species. The thermally activated chemical species is urea, a urea derivative, or a carbamate. The thermally activated chemical agent is thermally activated at or above a threshold temperature less than 200 C. In addition, the method includes (b) thermally activating the thermally activated chemical species in the aqueous solution during or after (a) at a temperature equal to or greater than the threshold temperature to produce carbon-dioxide and at least one of ammonia, amine, and alkanolamine within the reservoir. Further, the method includes (c) increasing the water wettability of the subterranean formation in response to the thermally activation in (b). Still further, the method includes (d) waterflooding the reservoir with water after (a), (b) and (c).

A method for producing hydrocarbons within a reservoir includes (a) injecting an aqueous solution into the reservoir. The aqueous solution includes water and a thermally activated chemical species. The thermally activated chemical species is urea, a urea derivative, or a carbamate. The thermally activated chemical agent is thermally activated at or above a threshold temperature less than 200 C. In addition, the method includes (b) thermally activating the thermally activated chemical species in the aqueous solution during or after (a) at a temperature equal to or greater than the threshold temperature to produce carbon-dioxide and at least one of ammonia, amine, and alkanolamine within the reservoir. Further, the method includes (c) increasing the water wettability of the subterranean formation in response to the thermally activation in (b). Still further, the method includes (d) waterflooding the reservoir with water after (a), (b) and (c).

Reservoir simulations may be executed in a high performance computing cloud cluster (530) provisioned within a cloud computing environment (450) and accessible by graphical pre- and/or post-processors (410) resident on a computer system (402) that is external to the cloud computing environment.

Reservoir simulations may be executed in a high performance computing cloud cluster (530) provisioned within a cloud computing environment (450) and accessible by graphical pre- and/or post-processors (410) resident on a computer system (402) that is external to the cloud computing environment.

Apparatus and methods for energizing well operations fluids, including a fluid energizing device directly or operatively connected between first and second conduits. The fluid energizing device includes a chamber. A first fluid enters the chamber from the first conduit, and a second fluid enters the chamber from the second conduit and energizes the first fluid within the chamber. A third conduit conducts the energized first fluid from the chamber to a wellhead.

A method includes injecting an aqueous-based injection fluid into a wellbore at a first temperature, where the aqueous-based injection fluid includes phase-changing nanodroplets having a liquid core and a shell. The method also includes exposing the phase-changing nanodroplets to a second temperature in the wellbore that is greater than or equal to a boiling point of the liquid core to change a liquid in the liquid core to a vapor phase and expand the phase-changing nanodroplets, thus removing debris from the wellbore and surrounding area.

A method includes injecting an aqueous-based injection fluid into a wellbore at a first temperature, where the aqueous-based injection fluid includes phase-changing nanodroplets having a liquid core and a shell. The method also includes exposing the phase-changing nanodroplets to a second temperature in the wellbore that is greater than or equal to a boiling point of the liquid core to change a liquid in the liquid core to a vapor phase and expand the phase-changing nanodroplets, thus removing debris from the wellbore and surrounding area.

Embodiments described herein include a system for generating a drainage radius log per well that includes a computing device that receives well data associated with a plurality of wells, utilizes the well production data to calculate a value for cumulative liquid produced by each of the plurality of wells for a predetermined time period, and utilizes at least a portion of the well data to calculate a fractional contribution for each of the plurality of wells. In some embodiments the computing device utilizes the value for cumulative liquid produced for each of the plurality of wells and the fractional contribution to calculate a cumulative liquid production for each of the plurality of wells, utilizes the cumulative liquid production to calculate the drainage radius log for each of the plurality of wells, and outputs the drainage radius log for display.