Abstract: A wellbore servicing method comprising transporting a pump unit comprising a unit controller and pumping equipment to a wellsite. Executing a design process on the unit controller to determine a concentration of a wellbore treatment fluid at a wiper plug within an oilfield tubular. The design process utilizes a CFD model to generate a static mesh representative of the geometry of the oilfield tubular, locate the wiper plug within the static mesh, and determine a fluid velocity on each side of the wiper plug with flexible static mesh cells. The CFD model can generate a prediction of the concentration of the wellbore treatment fluids in response to the wiper plug reaching a target location within the oilfield tubular.

Abstract: Temperature data collected from a distributed temperature sensing system may be used to prepare a temporal thermal profile of the wellbore. The temporal thermal profile may be used to determine a generalized heat transfer coefficient (k) and/or a generalized geothermal profile (Tae). The temporal thermal profile and the generalized heat transfer coefficient (k) and/or the generalized geothermal profile (Tae) may be used to estimate thermal properties of a wellbore, such as well as fluid and flow characteristics. A heat of hydration index may also be determined based on the temporal thermal profile.

Abstract: A method for controlling, tailoring, monitoring and executing a pumping operation of a wellbore treatment into a wellbore with an advisory process accessing pumping simulation results from a pumping model group. The advisory process can determine a change in the wellbore environment by comparing periodic datasets indicative of a pumping operation to a set of operational threshold values. The advisory process can identify the change in the wellbore environment from pumping simulation results generated by a pumping model group with pumping model inputs comprising portions of the periodic datasets. The advisory process can generate a modified pumping procedure in response to the identification of the change in the wellbore environment. The pumping model group can generate and forecast a probability of the pumping operation achieving a job objective.

Abstract: Locating a loss zone while cementing a well casing in a well bore includes: inserting a fiber-optic cable into the well bore, wherein the fiber optic cable is part of one or more Distributed Fiber-Optic Sensing (DFOS) systems; detecting a loss circulation signature, while cementing the well casing, at a point along the fiber-optic cable by at least one of the one or more DFOS systems; and locating the loss zone within the well bore based on the point along the fiber-optic cable at which the loss circulation signature was detected.

Abstract: A method for identifying zones in an annulus with poor cementing that may include deploying a fiber optic cable within the wellbore, creating a temperature gradient in the wellbore, and collecting temperature data over a period of time as the wellbore returns to a thermal equilibrium. The method may also include comparing the temperature data collected by the fiber optic cable at one or more locations to predicted temperature data over the period of time at the one or more locations to identify locations where the measured temperature data deviates from the predicted temperature data for identifying locations or zones of the annulus that have poor cementing.

Abstract: Methods of the present disclosure relate to designing lost circulation material (LCM) based on permeability of filter cake. A method comprises determining if a lost circulation material (LCM) has the potential to bridge a fracture, the fracture extending from a wellbore; determining a permeability of filter cake formed due to the LCM, wherein the permeability is determined if the LCM has the potential to bridge the fracture; and formulating a composition that includes the LCM, to control losses from the wellbore.

Abstract: A method of cementing may include: providing a first solid particulate material; measuring at least one physicochemical property of the first solid particulate material; correlating the at least one physicochemical property of the first solid particulate material to at least one physicochemical property of a second solid particulate material and at least one physicochemical of a third solid particulate material; determining if a result of the step of correlating meets an operational parameter; and preparing a cement slurry which meets the operational parameter.

Abstract: A method of designing a fluid loss control treatment for a low pressure zone within a wellbore from drilling datasets indicative of drilling the wellbore. The design process can determine a fluid loss rate and a fracture location from the drilling dataset. The design process may determine a particle type to form an interface with a filter property at the fracture location by inputting a fracture geometry into a particle model. The filter property of the interface includes a porosity value, a permeability value, or combinations thereof that exceeds a threshold value. The design process may generate a fluid loss control treatment comprising a quantity of particles and a volume of carrier fluid for the fracture geometry within the wellbore.

Abstract: A system and method including modeling wellbore conditions and plug properties to predetermine the dissolution time of a plug under wellbore conditions for use in a well operation. The system and method provide an estimate of how long a dissolvable plug will remain viable based on its composition and the conditions in the wellbore. Once a plug has been selected or once wellbore conditions have been determined, the plug and/or conditions can be tested in the lab to confirm suitability prior to use downhole.

Abstract: A method for identifying zones in an annulus with poor cementing that may include deploying a fiber optic cable within the wellbore, creating a temperature gradient in the wellbore, and collecting temperature data over a period of time as the wellbore returns to a thermal equilibrium. The method may also include comparing the temperature data collected by the fiber optic cable at one or more locations to predicted temperature data over the period of time at the one or more locations to identify locations where the measured temperature data deviates from the predicted temperature data for identifying locations or zones of the annulus that have poor cementing.

Abstract: Methods and systems are provided for designing and determining a well service in the presence of loss, including the volume, rates, and duration of pumping of fluids in the presence of losses. A method of designing services for wellbores includes calibrating a loss circulation model with input comprising wellbore state to update the loss circulation model with formation loss zone characteristics; applying the loss circulation model to output at least a prediction of loss rate; and designing a wellbore service at least partially based on the prediction of the loss rate.

Abstract: Techniques of the present disclosure relate to designing a fluid. A method comprises receiving at least one known parameter for a fluid design; receiving at least one constraint for the fluid design; estimating at least one unknown parameter for the fluid design; calculating displacement efficiency of the fluid design based on the at least one known parameter and at least one estimated parameter; and producing a designed fluid based on the displacement efficiency.

Abstract: Aspects of the subject technology relate to systems and methods for determining cement barrier quality of a cementing process. Systems and methods are provided for receiving data from a distributed acoustic sensing fiber optic line positioned proximate to cement barrier of a wellbore, determining at least one zonal isolation in the cement barrier based on the data received from the distributed acoustic sensing fiber optic line, and compiling a cement bond log based on the determining of the at least one zonal isolation in the cement barrier.

Abstract: A system and method including modeling wellbore conditions and plug properties to predetermine the dissolution time of a plug under wellbore conditions for use in a well operation. The system and method provide an estimate of how long a dissolvable plug will remain viable based on its composition and the conditions in the wellbore. Once a suitable plug has been selected or once suitable wellbore conditions have been determined, the plug and/or conditions can be tested in the lab to confirm suitability prior to use downhole.

Abstract: A method of designing a cement pumping procedure of a wellbore isolation barrier with a design application receiving customer inputs comprising a plurality of wellbore data and a job objective. The design application can retrieve a cement pumping procedure from a data source comprising a series of sequential steps to achieve the job objective. The design application can load the customer inputs into the cement pumping procedure, access a database of best practices, calculate a probability score for achieving the job objective based on a model, and recommend modifying one or more steps of the cement pumping procedure with one or more best practices in response to the probability score being below a threshold.

Abstract: A method of designing a cement composition may include: minimizing an objective function subject to a plurality of constraints to produce a cement composition including at least one cement component and water; and preparing the cement composition.

Abstract: A method may include: analyzing each of a group of inorganic particles to generate data about physicochemical properties of each of the inorganic particles; and generating a correlation between a reactivity index of each of the inorganic particles and the data.

Abstract: The equivalent circulating density (“ECD”) in a wellbore may be managed during a wellbore operation using ECD models that take into account the rheology of the wellbore fluid and the rotational speed of tubulars in the wellbore. For example, a method may include rotating a rotating tubular in a stationary conduit while flowing a fluid through an annulus between the rotating tubular and the stationary conduit; calculating an equivalent circulating density (“ECD”) of the fluid where a calculated viscosity of the fluid is based on an ECD model ?_eff=f(? ?_eff)*h(Re), wherein ?_eff is the viscosity of the fluid, ? ?_eff is an effective shear rate of the fluid, and Re is a Reynold's number for the fluid for the rotational speed of the rotating tubular; and changing an operational parameter of the wellbore operation to maintain or change the ECD of the fluid.

Abstract: A method may include: providing a model of cement induction time; designing a cement composition, based at least partially, on the model of cement induction time; and preparing the cement composition.

Abstract: System and methods for detecting a composition in a wellbore during a cementing operation. An electrochemical cell can be disposed towards an end of a wellbore. The electrochemical cell can generate electrical energy in response to a physical presence of a composition at the electrochemical cell. The composition can be pumped from a surface of the wellbore during a cementing operation of the wellbore. Further, a telemetry signal indicating the physical presence of the composition at the electrochemical cell can be generated based on the electrical energy generated by the electrochemical cell. As follows, the telemetry signal can be transmitted to the surface of the wellbore.