Abstract: Methods and systems for monitoring and controlling a hydraulic fracturing operation to generate a real-time treatment plan are provided. The methods of the present disclosure include providing a treatment fluid; introducing the treatment fluid into a wellbore penetrating at least a first portion of a subterranean formation at or above a pressure sufficient to create or enhance one or more formation entry points in the subterranean formation; measuring one or more properties of the treatment fluid or downhole conditions within the subterranean formation; creating a treatment plan substantially in real-time including one or more plans selected from the group consisting of: a proppant placement plan, a fluid placement plan, a completion plan, and any combination thereof, wherein the treatment plan is based at least partially on the one or more properties of the treatment fluid or downhole conditions; and treating at least the first portion of the subterranean formation in accordance with the treatment plan.

Abstract: Methods and systems for monitoring and controlling a hydraulic fracturing operation to generate a real-time treatment plan are provided. The methods of the present disclosure include providing a treatment fluid; introducing the treatment fluid into a wellbore penetrating at least a first portion of a subterranean formation at or above a pressure sufficient to create or enhance one or more formation entry points in the subterranean formation; measuring one or more properties of the treatment fluid or downhole conditions within the subterranean formation; creating a treatment plan substantially in real-time including one or more plans selected from the group consisting of: a proppant placement plan, a fluid placement plan, a completion plan, and any combination thereof, wherein the treatment plan is based at least partially on the one or more properties of the treatment fluid or downhole conditions; and treating at least the first portion of the subterranean formation in accordance with the treatment plan.

Abstract: A pumping schedule for stimulating a well can be dynamically optimized. For example, a layer in a well can be determined to have a highest value for a characteristic. The layer can be assigned as a first layer in an ordered list. A pump rate and type of fluid to pump into the wellbore for reducing an amount of blockage to below a threshold value can be determined based on a feature of the first layer. The blockage can reduce a flow of a production fluid from the first layer into the wellbore. Changes to values for the characteristics of layers in the well resulting from pumping the fluid can be determined. Another layer in the well can be determined to have the highest value for the characteristic as a result of pumping the fluid into the wellbore and can be assigned as the first layer in the ordered list.

Abstract: A pumping schedule for stimulating a well can be dynamically optimized. For example, a layer in a well can be determined to have a highest value for a characteristic. The layer can be assigned as a first layer in an ordered list. A pump rate and type of fluid to pump into the wellbore for reducing an amount of blockage to below a threshold value can be determined based on a feature of the first layer. The blockage can reduce a flow of a production fluid from the first layer into the wellbore. Changes to values for the characteristics of layers in the well resulting from pumping the fluid can be determined. Another layer in the well can be determined to have the highest value for the characteristic as a result of pumping the fluid into the wellbore and can be assigned as the first layer in the ordered list.

Abstract: A system includes at least one processor, and a memory coupled to the at least one processor having instructions stored therein. When executed by the at least one processor, the instructions cause the at least one processor to perform functions including functions to: apply a treatment at a first well in the subterranean formation, wherein the treatment is for stimulating production; perform a step down analysis of the first well at each of a plurality of stages of the first well; determine a downhole flow distribution at each of the plurality of stages; develop a model for correlating the downhole flow distribution and the step down analysis at each of the plurality of stages; use the developed model to estimate a downhole flow distribution at a stage of a second well; and determine whether to bypass a deployment of the diverter material at the stage of the second well based on the estimated downhole flow distribution.