Abstract: Computerized systems and methods for segment based approach to routing picking are disclosed. The systems and methods may include performing steps for: receiving a floorplan of a first set of location IDs, wherein the first set of location IDs correspond to locations of multiple inventory items arranged in a floor; generating one or more base segments that connect the first set of location IDs; generating one or more route segments by combining the one or more base segments with one or more demand points corresponding to a second set of location IDs; generating one or more dispatch routes through the one or more route segments based on an optimal routing of resources that maximizes a density metric of the multiple inventory items included in the one or more dispatch routes; and assigning a first user to a combination of the one or more dispatch routes.

Abstract: Systems and methods for real-time optimization of stimulation treatments in a hydrocarbon reservoir by controlling a simulated stimulation treatment schedule for a main fracture stimulation treatment stage using a predicted net pressure in a cluster of fractures representing a dominant fracture for the main fracture stimulation treatment stage.

Abstract: Systems and methods for real-time optimization of stimulation treatments in a hydrocarbon reservoir by controlling a simulated stimulation treatment schedule for a main fracture stimulation treatment stage using a predicted net pressure in a cluster of fractures representing a dominant fracture for the main fracture stimulation treatment stage.

Abstract: Methods and systems for detection of crossflow and quantification of crossflow effects on fluid distribution during multistage injection treatments of hydrocarbon bearing reservoir formations. A low rate injection stage is applied after a main (high rate) fluid injection stage of a multistage injection treatment process. Wellbore temperature measurements can be utilized along with an inversion process to detect any crossflow and quantify its effects on fluid distribution during the main injection stage. After the effects of any detected crossflow on the fluid distribution are quantified, the effectiveness of the multistage injection treatment can be analyzed and any adjustments or modifications to the treatment can be made accordingly.

Abstract: A method for optimized matrix acidizing, including a method for determining fracture pressure of a formation as a function of bottom hole temperature. First and second cycles of a step up rate test may be performed on the formation to be acidized at first and second test temperatures, respectively. From the first and second cycles, a mathematical relationship for fracture pressure of the formation as a function of bottom hole temperature may be formulated and integrated into a fluid placement simulator. A design matrix acidizing treatment plan accounting for an effect of bottom hole temperature on fracture gradient may simulated, and matrix acidizing treatment thereafter performed according to the design plan, thereby resulting in more accurate matrix acidizing treatment and minimization of inefficient fluid placement by adherence to actual formation fracture pressure limits.

Abstract: Methods and systems are presented in this disclosure for detection of crossflow and quantification of crossflow effects on fluid distribution during multistage injection treatments of hydrocarbon bearing reservoir formations. A low rate injection stage is applied after a main (high rate) fluid injection stage of a multistage injection treatment process. Wellbore temperature measurements can be utilized along with an inversion process to detect any crossflow and quantify its effects on fluid distribution during the main injection stage. After the effects of any detected crossflow on the fluid distribution are quantified, the effectiveness of the multistage injection treatment can be analyzed and any adjustments or modifications to the treatment can be made accordingly.

Abstract: Methods and systems for determining acidizing fluid injection rates for stimulation of a subterranean formation arc provided. In one embodiment, methods comprise: selecting a first injection rate for injecting an acidizing fluid into a subterranean formation; calculating a first objective function based on the first injection rate; selecting a second injection rate for injecting the acidizing fluid into the subterranean formation; calculating a second objective function based on the second injection rate; comparing the second objective function with the first objective function to determine whether the second objective function is indicative of more effective stimulation, less effective stimulation, or the same stimulation as the first objective function; and selecting a design rate for injecting the acidizing fluid into the subterranean formation.

Abstract: A method for optimized matrix acidizing, including a method for determining fracture pressure of a formation as a function of bottom hole temperature. First and second cycles of a step up rate test may be performed on the formation to be acidized at first and second test temperatures, respectively. From the first and second cycles, a mathematical relationship for fracture pressure of the formation as a function of bottom hole temperature may be formulated and integrated into a fluid placement simulator. A design matrix acidizing treatment plan accounting for an effect of bottom hole temperature on fracture gradient may simulated, and matrix acidizing treatment thereafter performed according to the design plan, thereby resulting in more accurate matrix acidizing treatment and minimization of inefficient fluid placement by adherence to actual formation fracture pressure limits.

Abstract: Methods and systems for determining acidizing fluid injection rates for stimulation of a subterranean formation arc provided. In one embodiment, methods comprise: selecting a first injection rate for injecting an acidizing fluid into a subterranean formation; calculating a first objective function based on the first injection rate; selecting a second injection rate for injecting the acidizing fluid into the subterranean formation; calculating a second objective function based on the second injection rate; comparing the second objective function with the first objective function to determine whether the second objective function is indicative of more effective stimulation, less effective stimulation, or the same stimulation as the first objective function; and selecting a design rate for injecting the acidizing fluid into the subterranean formation.