WO2023149873A1

WO2023149873A1 - Wellbore deposition monitoring tool

Info

Publication number: WO2023149873A1
Application number: PCT/US2022/014911
Authority: WO
Inventors: Joseph E. Patterson; Ramesh Anant KINI
Original assignee: Chevron U.S.A. Inc.
Priority date: 2022-02-02
Filing date: 2022-02-02
Publication date: 2023-08-10

Abstract

A flow rate in a wellbore and a measured frictional pressure drop in the wellbore are used to determine a measured friction loss factor for the wellbore. The flow rate in the wellbore and an ideal frictional pressure drop in the wellbore are used to determine an ideal friction loss factor for the wellbore. A ratio of the measured friction loss factor and the ideal friction loss factor is used to monitor deposit buildup in the wellbore

Description

WELLBORE DEPOSITION MONITORING TOOL

FIELD

[0001] The present disclosure relates generally to the field of monitoring wellbore deposition.

BACKGROUND

[0002] Materials may build up inside a wellbore during operation. Buildup of materials inside the wellbore may reduce the efficiency of the wellbore and/or may pose risk of damage to the wellbore.

SUMMARY

[0003] This disclosure relates to monitoring wellbore deposition. Flow rate information for a wellbore, measured pressure drop information for the wellbore, operating information for the wellbore, and/or other information may be obtained. The flow rate information may define a flow rate through the wellbore. The measured pressure drop information may define a measured frictional pressure drop in the wellbore. The operating information may define operating characteristics of the wellbore. An ideal frictional pressure drop in the wellbore may be determined based on the operating characteristics of the wellbore and/or other information. A measured friction loss factor for the wellbore may be determined based on the measured frictional pressure drop in the wellbore, the flow rate through the wellbore, and/or other information. An ideal friction loss factor for the wellbore may be determined based on the ideal frictional pressure drop in the wellbore, the flow rate through the wellbore, and/or other information. A wellbore deposition indicator value may be determined based on the measured friction loss factor, the ideal friction loss factor, and/or other information. Deposition monitoring for the wellbore based on the wellbore deposition indicator value may be facilitated.

[0004] A system for monitoring wellbore deposition may include one or more electronic storage, one or more processors and/or other components. The electronic storage may store information relating to a wellbore, flow rate information, information relating to a flow rate through the wellbore, measured press loss information, information relating to a measured frictional pressure drop in the wellbore, operating information, information relating to operating characteristics of the wellbore, information relating to an ideal frictional pressure drop in the wellbore, information relating to a measured friction loss factor, information relating to an ideal friction loss factor, information relating to a wellbore deposition indicator value, information relating to deposition monitoring, and/or other information.

[0005] The processor(s) may be configured by machine-readable instructions.

Executing the machine-readable instructions may cause the processor(s) to facilitate monitoring wellbore deposition. The machine-readable instructions may include one or more computer program components. The computer program components may include one or more of a flow rate information component, a measured pressure drop information component, an operating information component, an ideal frictional pressure drop component, a measured friction loss factor component, an ideal friction loss factor component, a wellbore deposition indicator component, a deposition monitoring component, and/or other computer program components.

[0006] The flow rate information component may be configured to obtain flow rate information and/or other information for a wellbore. The flow rate information may define a flow rate through the wellbore.

[0007] The measured pressure drop information component may be configured to obtain measured pressure drop information and/or other information for the wellbore. The measured pressure drop information may define a measured frictional pressure drop in the wellbore. In some implementations, the measured frictional pressure drop in the wellbore may be determined based on a difference between a measured pressure drop in the wellbore and a hydrostatic pressure drop in the wellbore.

[0008] The operating information component may be configured to obtain operating information and/or other information for the wellbore. The operating information may define operating characteristics of the wellbore.

[0009] The ideal frictional pressure drop component may be configured to determine an ideal frictional pressure drop in the wellbore. The ideal frictional pressure drop in the wellbore may be determined based on the operating characteristics of the wellbore and/or other information. [0010] The measured friction loss factor component may be configured to determine a measured friction loss factor for the wellbore. The measured friction loss factor for the wellbore may be determined based on the measured frictional pressure drop in the wellbore, the flow rate through the wellbore, and/or other information.

[0011] The ideal friction loss factor component may be configured to determine an ideal friction loss factor for the wellbore. The ideal friction loss factor for the wellbore may be determined based on the ideal frictional pressure drop in the wellbore, the flow rate through the wellbore, and/or other information.

[0012] The wellbore deposition indicator component may be configured to determine a wellbore deposition indicator value. The wellbore deposition indicator value may be determined based on the measured friction loss factor, the ideal friction loss factor, and/or other information. In some implementations, the wellbore deposition indicator value may be determined as a ratio of the measured friction loss factor and the ideal friction loss factor. In some implementations, the wellbore deposition indicator value may include a dimensionless parameter that standardizes monitoring of wellbore deposition across different wellbores.

[0013] The deposition monitoring component may be configured to facilitate deposition monitoring for the wellbore. The deposition monitoring for the wellbore may be performed based on the wellbore deposition indicator value and/or other information.

[0014] In some implementations, facilitation of the deposition monitoring for the wellbore based on the wellbore deposition indicator value may include monitoring of an amount of deposit formation on the wellbore using the wellbore deposition indicator value and/or other information.

[0015] In some implementations, facilitation of the deposition monitoring for the wellbore based on the wellbore deposition indicator value may include determination of effectiveness of a deposition preventative measure to inhibit deposit formation on the wellbore using the wellbore deposition indicator value and/or other information.

[0016] In some implementations, facilitation of the deposition monitoring for the wellbore based on the wellbore deposition indicator value may include determination of effectiveness of a deposition remedial measure to remove deposit formation from the wellbore using the wellbore deposition indicator value and/or other information.

[0017] In some implementations, facilitation of the deposition monitoring for the wellbore based on the wellbore deposition indicator value may include determination of deposit breakaway from the wellbore using the wellbore deposition indicator value and/or other information.

[0018] In some implementations, facilitation of the deposition monitoring for the wellbore based on the wellbore deposition indicator value may include generation of a plot of the wellbore deposition indicator value over time. A threshold value that separates significant deposits from insignificant deposits may be overlaid on top of the plot of the wellbore deposition indicator value over time.

[0019] These and other objects, features, and characteristics of the system and/or method disclosed herein, as well as the methods of operation and functions of the related elements of structure and the combination of parts and economies of manufacture, will become more apparent upon consideration of the following description and the appended claims with reference to the accompanying drawings, all of which form a part of this specification, wherein like reference numerals designate corresponding parts in the various figures. It is to be expressly understood, however, that the drawings are for the purpose of illustration and description only and are not intended as a definition of the limits of the invention. As used in the specification and in the claims, the singular form of “a,” “an,” and “the” include plural referents unless the context clearly dictates otherwise.

BRIEF DESCRIPTION OF THE DRAWINGS

[0020] FIG. 1 illustrates an example system for monitoring wellbore deposition.

[0021] FIG. 2 illustrates an example method for monitoring wellbore deposition.

[0022] FIG. 3 illustrates example wellbores.

[0023] FIG. 4 illustrates example changes in measured friction loss factor and wellbore deposition indicator value. DETAILED DESCRIPTION

[0024] The present disclosure relates to monitoring wellbore deposition. A flow rate in a wellbore and a measured frictional pressure drop in the wellbore are used to determine a measured friction loss factor for the wellbore. The flow rate in the wellbore and an ideal frictional pressure drop in the wellbore are used to determine an ideal friction loss factor for the wellbore. A ratio of the measured friction loss factor and the ideal friction loss factor is used to monitor deposit buildup in the wellbore.

[0025] The methods and systems of the present disclosure may be implemented by a system and/or in a system, such as a system 10 shown in FIG. 1 . The system 10 may include one or more of a processor 11, an interface 12 (e.g., bus, wireless interface), an electronic storage 13, a display 14, and/or other components. Flow rate information for a wellbore, measured pressure drop information for the wellbore, operating information for the wellbore, and/or other information may be obtained by the processor 11. The flow rate information may define a flow rate through the wellbore. The measured pressure drop information may define a measured frictional pressure drop in the wellbore. The operating information may define operating characteristics of the wellbore. An ideal frictional pressure drop in the wellbore may be determined by the processor 11 based on the operating characteristics of the wellbore and/or other information. A measured friction loss factor for the wellbore may be determined by the processor 11 based on the measured frictional pressure drop in the wellbore, the flow rate through the wellbore, and/or other information. An ideal friction loss factor for the wellbore may be determined by the processor 11 based on the ideal frictional pressure drop in the wellbore, the flow rate through the wellbore, and/or other information. A wellbore deposition indicator value may be determined by the processor 11 based on the measured friction loss factor, the ideal friction loss factor, and/or other information. Deposition monitoring for the wellbore based on the wellbore deposition indicator value may be facilitated by the processor 11.

[0026] The electronic storage 13 may be configured to include electronic storage medium that electronically stores information. The electronic storage 13 may store software algorithms, information determined by the processor 11 , information received remotely, and/or other information that enables the system 10 to function properly. For example, the electronic storage 13 may store information relating to a wellbore, flow rate information, information relating to a flow rate through the wellbore, measured press loss information, information relating to a measured frictional pressure drop in the wellbore, operating information, information relating to operating characteristics of the wellbore, information relating to an ideal frictional pressure drop in the wellbore, information relating to a measured friction loss factor, information relating to an ideal friction loss factor, information relating to a wellbore deposition indicator value, information relating to deposition monitoring, and/or other information.

[0027] The display 14 may refer to an electronic device that provides visual presentation of information. The display 14 may include a color display and/or a non-color display. The display 14 may be configured to visually present information. The display 14 may present information using/within one or more graphical user interfaces. For example, the display 14 may present information relating to a wellbore, flow rate information, information relating to a flow rate through the wellbore, measured press loss information, information relating to a measured frictional pressure drop in the wellbore, operating information, information relating to operating characteristics of the wellbore, information relating to an ideal frictional pressure drop in the wellbore, information relating to a measured friction loss factor, information relating to an ideal friction loss factor, information relating to a wellbore deposition indicator value, information relating to deposition monitoring, and/or other information.

[0028] A wellbore may refer to a hole that is drilled in the ground. A wellbore may be drilled in the ground for exploration and/or recovery of resources in the ground, such as water or hydrocarbons. For example, a wellbore may be drilled for production of hydrocarbons (e.g., as a production well, as an injection well). A wellbore may be uncased or encased with protective materials, such as steel and/or cement. During operation of the wellbore (e.g., for resource extraction, for enhancing resource recovery, for gas lift), undesired materials may build up on the walls of the wellbore. Such buildup of materials on the walls of the wellbore may be referred to as wellbore deposition. For example, organic and/or inorganic materials may build up on the walls of the wellbore over time, progressively reducing the flowing path of fluids (e.g., oil, gas) inside the wellbore, which may cause undesired pressure drop in the wellbore and reduce the efficiency of the well. For example, the amount of hydrocarbon production through the wellbore and/or the effectiveness of water flooding through the wellbore to enhance oil recovery may be decreased. Buildup of materials on the wellbore may pose risk of danger to the wellbore. Danger to the wellbore may include possible damage to the wellbore and/or wellbore equipment when the materials on the wellbore breakaway. Danger to the wellbore may include erratic changes in flow of fluid through the wellbore when the materials on the wellbore breakaway.

[0029] FIG. 3 illustrates example wellbores 302, 304. The wellbore 302 may be clean such that flow of fluid through the wellbore is unrestricted. The wellbore 304 may include deposit 310 on the wall of the wellbore. The deposit 310 may restrict the flow of fluid through the wellbore 304, reducing the efficiency/effectiveness of the wellbore. Breakaway of the deposit 310 from the wellbore 304 may cause damage to the wellbore 304 and/or equipment being used on the wellbore 304. Breakaway of the deposit 310 from the wellbore 304 may cause erratic changes in how fluid flows through the wellbore 304.

[0030] Wellbore deposition may be challenging to monitor. While buildup of materials on the wellbore may cause change in pressure drop in the wellbore, change in pressure drop in the wellbore observed over time may be attributed to noise in measurements or other naturally occurring factors. For example, as production matures, reservoir and wellbore pressures, water rates, gas rates, and fluid flow patterns may change. Well operators may not be able to distinguish between naturally occurring changes in the wellbore/reservoir versus changes caused by wellbore deposition. To identify wellbore deposition, well operators may analyze trends of multiple wellbore operating characteristics. For example, well operators may analyze trends of changes in wellhead pressure, downhole pressure, wellbore pressure drop, fluid composition, flow rate, production rate, temperature, and/or other wellbore operating characteristics to identify wellbore deposition. However, identifying wellbore deposition by using trends of multiple wellbore operating characteristics may be difficult, complicated, and affected by subjective interpretations of trends. It may not be possible to use the trends of multiple wellbore operating characteristics to differentiate between changes caused by wellbore deposition, changes caused by changes in wellbore operation, and changes caused by changes in the reservoir.

[0031] Additionally, analysis of wellbore deposition performed for one wellbore may not be comparable to analysis wellbore deposition performed for another wellbore. Analysis of wellbore deposition may be specific to the type/configu ration of the wellbore, the type/mixture of fluid inside the wellbore, the operating characteristics of the wellbore, the reservoir in which the wellbore in operating, and/or other factors specific to the wellbore.

[0032] The present disclosure provides a tool to generate a single dimensionless parameter that may be used to monitor wellbore deposition. Rather than requiring analysis of the trends of multiple wellbore operating characteristics to identify wellbore deposition, the present disclosure simplifies the monitoring of wellbore deposition to trending a single dimensionless parameter that captures the amount and/or type of materials built up on the wellbore.

[0033] This single dimensionless parameter may capture the effects of changing temperature, pressure, composition, and flow rate of the wellbore. That is, multiple wellbore operating characteristics may be consolidated into the single dimensionless parameter. Computation of the single dimensionless parameter value may account for the impact of changing wellbore operating characteristics and may decouple the impact of changes in wellbore operating characteristics from wellbore deposition monitoring. The present disclosure may improve the signal to noise ratio for wellbore deposition monitoring by accounting for the impact of field conditions through physics-based modeling. In some implementations, one or more assumptions about the wellbore operating characteristics may be made in computation of the single dimensionless parameter value. For example, the fluid flowing through the wellbore may be assumed to be incompressible fluid (single phase). The wellbore may be assumed to be a vertical wellbore. The deposit of materials on the wellbore may be assumed to be uniform. The single dimensionless parameter value may be assumed to be constant along the wellbore.

[0034] The use of the single dimensionless parameter to monitor wellbore deposition enables standardization of wellbore deposition across different wellbores (e.g., different wells, different types of wellbores, same wellbore with different operating conditions, wellbores in different reservoirs). For example, the single dimensionless parameter may standardize wellbore deposition monitoring regardless of asset association or level of maturity of the wellbores. The present disclosure enables early detection of formation of deposits on the wellbores, and allows for simple evaluation of the effectiveness of mitigation and remediation efforts. For example, the present disclosure may be utilized to monitor the rate of deposition formation on a wellbore over time, monitor how effective treating of the wellbore (e.g., with chemicals) is at preventing wellbore deposition, and/or monitor how effective remediation measures are at removing deposition from the wellbore.

[0035] Referring back to FIG. 1, the processor 11 may be configured to provide information processing capabilities in the system 10. As such, the processor 11 may comprise one or more of a digital processor, an analog processor, a digital circuit designed to process information, a central processing unit, a graphics processing unit, a microcontroller, an analog circuit designed to process information, a state machine, and/or other mechanisms for electronically processing information. The processor 11 may be configured to execute one or more machine-readable instructions 100 to facilitate monitoring wellbore deposition. The machine-readable instructions 100 may include one or more computer program components. The machine-readable instructions 100 may include a flow rate information component 102, a measured pressure drop information component 104, an operating information component 106, an ideal frictional pressure drop component 108, a measured friction loss factor component 110, an ideal friction loss factor component 112, a wellbore deposition indicator component 114, a deposition monitoring component 116, and/or other computer program components. [0036] The flow rate information component 102 may be configured to obtain flow rate information and/or other information for a wellbore. Obtaining flow rate information may include one or more of accessing, acquiring, analyzing, determining, examining, generating, identifying, loading, locating, measuring, opening, receiving, retrieving, reviewing, selecting, storing, and/or otherwise obtaining the flow rate information. The flow rate information component 102 may obtain flow rate information from one or more locations. For example, the flow rate information component 102 may obtain flow rate information from a storage location, such as the electronic storage 13, electronic storage of a device accessible via a network, and/or other locations. The flow rate information component 102 may obtain flow rate information from one or more hardware components (e.g., a computing device) and/or one or more software components (e.g., software running on a computing device). In some implementations, the flow rate information may be obtained from one or more users. For example, a user may interact with a computing device to input the flow rate information (e.g., upload the flow rate information, specify the flow rate through the wellbore).

[0037] The flow rate information may define a flow rate through the wellbore. The flow rate information may define the flow rate through the wellbore by characterizing, describing, identifying, quantifying, reflecting, and/or otherwise defining the flow rate through the wellbore. The flow rate information may define a flow rate of fluid through the wellbore. For example, the flow rate information may define a total flow rate of production fluids (e.g., gas hydrocarbon, liquid hydrocarbon, and produced water) through the wellbore. A flow rate may refer to a quantification of fluid movement. A flow rate may include mass flow rate, a volumetric flow rate, and/or other flow rate. The flow rate information may define a flow rate through one or more portions of the wellbore. The flow rate information may define a flow rate through the entirety of the wellbore.

[0038] The flow rate information may define a measured flow rate through the wellbore. For example, the actual flow rate of fluid through the wellbore may be measured through use of one or more flow sensors (e.g., flow meters) for the wellbore, and the measured flow rate may be defined by the flow rate information. [0039] The flow rate information may define a modeled flow rate through the wellbore. For example, the flow of fluid though the wellbore may be modeled on a computer using the operating characteristics of the wellbore (e.g., geometry of the wellbore; pressure, temperature, and/or fluid composition/properties inside the wellbore), and the modeled flow rate through the wellbore may be defined by the flow rate information.

[0040] The flow rate information may define a flow rate through a wellbore by including information that defines one or more content, qualities, attributes, features, and/or other aspects of the flow rate through the wellbore. For example, the flow rate information may define a flow rate through a wellbore by including information that specifies values of the measured and/or modeled flow rate through the wellbore, and/or information that is used to determine the measured and/or modeled flow rate through the wellbore. Other types of flow rate information are contemplated.

[0041] The measured pressure drop information component 104 may be configured to obtain measured pressure drop information and/or other information for the wellbore. Obtaining measured pressure drop information may include one or more of accessing, acquiring, analyzing, determining, examining, generating, identifying, loading, locating, measuring, opening, receiving, retrieving, reviewing, selecting, storing, and/or otherwise obtaining the measured pressure drop information. The measured pressure drop information component 104 may obtain measured pressure drop information from one or more locations. For example, the measured pressure drop information component 104 may obtain measured pressure drop information from a storage location, such as the electronic storage 13, electronic storage of a device accessible via a network, and/or other locations. The measured pressure drop information component 104 may obtain measured pressure drop information from one or more hardware components (e.g., a computing device) and/or one or more software components (e.g., software running on a computing device). In some implementations, the measured pressure drop information may be obtained from one or more users. For example, a user may interact with a computing device to input the measured pressure drop information (e.g., upload the measured pressure drop information, specify the measured frictional pressure drop flow rate in the wellbore). [0042] The measured pressure drop information may define a measured frictional pressure drop in the wellbore. The measured pressure drop information may define the measured frictional pressure drop in the wellbore by characterizing, describing, identifying, quantifying, reflecting, and/or otherwise defining the measured frictional pressure drop in the wellbore. A pressure drop in the wellbore may refer to a reduction of pressure between two points/locations along the wellbore. A frictional pressure drop in the wellbore may refer to a reduction of pressure between two points/location along the wellbore due to friction inside the wellbore. A measured frictional pressure drop in the wellbore may refer to a pressure drop in the wellbore due to friction inside the wellbore that is measured (indirectly, directly) using one or more sensors (e.g., wellhead pressure gauge, downhole pressure gauge). The amount of frictional pressure drop in the wellbore may be dependent on the fluid inside the wellbore, geometry of the wellbore, and/or the conditions inside the wellbore, such as flow velocity, viscosity of the fluid, density of the fluid, wellbore size, wellbore length, smoothness of the wellbore, number and/or types of values and fittings along the wellbore, amount of deposits along the wellbore, location of deposits along the wellbore, type of deposits along the wellbore, and/or other characteristics of the wellbore.

[0043] The measured pressure drop information may define a measured frictional pressure drop in a wellbore by including information that defines one or more content, qualities, attributes, features, and/or other aspects of the measured frictional pressure drop in the wellbore. For example, the measured pressure drop information may define a measured frictional pressure drop in the wellbore by including information that specifies values of the measured frictional pressure drop in the wellbore, and/or information that is used to determine the measured frictional pressure drop in the wellbore. Other types of measured pressure drop information are contemplated.

[0044] In some implementations, the measured frictional pressure drop in the wellbore may be determined based on a difference between a measured pressure drop in the wellbore and a hydrostatic pressure drop in the wellbore. A hydrostatic pressure drop in the wellbore may refer to a pressure drop in the wellbore due to force of gravity on the fluid inside the wellbore. The hydrostatic pressure drop in the wellbore may be modeled/calculated on a computing device using the operating characteristics of the wellbore. For example, the hydrostatic pressure drop in the wellbore may be modeled/calculated based on characterization of fluid inside the wellbore, thermodynamics models of the fluid inside the wellbore, geometry of the wellbore (e.g., size, length), and/or the conditions inside the wellbore.

[0045] For example, the measured frictional pressure drop in the wellbore may be determined by (1) obtaining pressure measurements at two points/locations along the wellbore (e.g., from a wellhead pressure gauge and a downhole pressure gauge), (2) calculating the difference between the pressure measurements to obtain the measured pressure drop in the wellbore, (3) determining a theoretical hydrostatic pressure drop in the wellbore using modeling, and (4) calculating the measured frictional pressure drop in the wellbore by subtracting the theoretical hydrostatic pressure drop in the wellbore from the measured pressure drop in the wellbore.

[0046] The operating information component 106 may be configured to obtain operating information and/or other information for the wellbore. Obtaining operating information may include one or more of accessing, acquiring, analyzing, determining, examining, generating, identifying, loading, locating, measuring, opening, receiving, retrieving, reviewing, selecting, storing, and/or otherwise obtaining the operating information. The operating information component 106 may obtain operating information from one or more locations. For example, the operating information component 106 may obtain operating information from a storage location, such as the electronic storage 13, electronic storage of a device accessible via a network, and/or other locations. The operating information component 106 may obtain operating information from one or more hardware components (e.g., a computing device) and/or one or more software components (e.g., software running on a computing device). In some implementations, the operating information may be obtained from one or more users. For example, a user may interact with a computing device to input the operating information (e.g., upload the operating information, specify the operating characteristics of the wellbore). [0047] The operating information may define operating characteristics of the wellbore. The operating information may define the operating characteristics of the wellbore by characterizing, describing, identifying, quantifying, reflecting, and/or otherwise defining the operating characteristics of the wellbore. An operating characteristic of a wellbore may refer to one or more features and/or one or more qualities of the wellbore during operation of the wellbore (e.g., for exploration and/or recovery of resources). Operation of the wellbore may refer to performance of work on and/or usage of the wellbore.

[0048] An operating characteristic of a wellbore may include one or more values of operating parameter(s) that define the operation of the wellbore. An operating characteristic of a wellbore may include status of how the wellbore is being used. An operating characteristic of a wellbore may include one or more characteristics of materials of, within, around, and/or near the wellbore. For example, an operating characteristic of a wellbore may include characteristic(s) of the wellbore itself (e.g., geometry of the wellbore, materials of the wellbore, conditions of the wellbore, smoothness of the wellbore, values and/or fittings along the wellbore), characteristic(s) of materials inside the wellbore (e.g., pressure, temperature, heat transfer characteristics, fluid composition/properties, flow velocity, viscosity of the fluid, density of the fluid, vertical lift profile correlations and correlation coefficients, emulsion viscosity relationship), and/or other operating characteristic of the wellbore.

[0049] The operating information may define operating characteristics of a wellbore by including information that defines one or more content, qualities, attributes, features, and/or other aspects of the operating characteristics of the wellbore. For example, the operating information may define operating characteristics of the wellbore by including information that specifies values of the operating characteristics in the wellbore, and/or information that is used to determine the operating characteristics of the wellbore. Other types of operating information are contemplated.

[0050] The ideal frictional pressure drop component 108 may be configured to determine an ideal frictional pressure drop in the wellbore. Determining an ideal frictional pressure drop in a wellbore include ascertaining, approximating, calculating, establishing, estimating, finding, identifying, obtaining, quantifying, selecting, setting, and/or otherwise determining the ideal frictional pressure drop in the wellbore. An ideal frictional pressure drop in a wellbore may refer to a reduction of pressure between two points/locations along the wellbore due to theoretical friction inside the wellbore. An ideal frictional pressure drop in a wellbore may refer to the frictional pressure drop that is modeled/calculated in the wellbore without any deposit on the wellbore. The amount of theoretical frictional pressure drop in the wellbore include the frictional pressure drop caused by friction along the surface of the wellbore wall. The amount of theoretical frictional pressure drop in the wellbore may include the frictional pressure drop that would be observed in the wellbore without any deposit. That is, the ideal frictional pressure drop in the wellbore may include the frictional pressure drop in a clean (no deposit) wellbore.

[0051] The ideal frictional pressure drop in the wellbore may be determined based on the operating characteristics of the wellbore and/or other information. For example, the ideal frictional pressure drop in the wellbore may be determined based on one or more of characteristic(s) of the wellbore itself (e.g., geometry of the wellbore, materials of the wellbore, conditions of the wellbore, smoothness of the wellbore, values and/or fittings along the wellbore), characteristic(s) of materials inside the wellbore (e.g., pressure, temperature, heat transfer characteristics, fluid composition/properties, flow velocity, viscosity of the fluid, density of the fluid, vertical lift profile correlations and correlation coefficients, emulsion viscosity relationship), and/or other operating characteristic of the wellbore. The ideal frictional pressure drop in the wellbore may be determined based on the flow rate through the wellbore (measured flow rate, modeled flow rate). For example, the ideal frictional pressure drop in the wellbore may be determined based on the flow rate through the wellbore, density of fluid flowing through the wellbore, length of the wellbore, internal diameter of the wellbore, flow coefficient, and cross sectional wetted area. The ideal frictional pressure drop in the wellbore may be modeled/calculated on a computer using the operating characteristics of the wellbore. Such modeling/calculation of the ideal frictional pressure drop in the wellbore may account for turbulent flow in one or more fluid flow equations. [0052] The measured friction loss factor component 110 may be configured to determine a measured friction loss factor for the wellbore. Determining a measured friction loss factor for a wellbore include ascertaining, approximating, calculating, establishing, estimating, finding, identifying, obtaining, quantifying, selecting, setting, and/or otherwise determining the measured friction loss factor for the wellbore. A measured friction loss factor for a wellbore may refer to one or more values that represent the amount of measured frictional pressure drop in the wellbore. The value of the measured friction loss factor for the wellbore may reflect/correspond to the value of measured frictional pressure drop in the wellbore.

[0053] The measured friction loss factor for the wellbore may be determined based on the measured frictional pressure drop in the wellbore, the flow rate through the wellbore, and/or other information. The measured friction loss factor for the wellbore may be determined using a relationship between the measured frictional pressure drop in the wellbore and the flow rate through the wellbore. For example, the measured friction loss factor (FLmeasured) for the wellbore may be determined as a ratio of the measured frictional pressure drop (APmeasured) for the wellbore and the flow rate (Q) squared, such as:

FLmeasured ⁼ AP measured

[0054] The ideal friction loss factor component 112 may be configured to determine an ideal friction loss factor for the wellbore. Determining an ideal friction loss factor for a wellbore include ascertaining, approximating, calculating, establishing, estimating, finding, identifying, obtaining, quantifying, selecting, setting, and/or otherwise determining the ideal friction loss factor for the wellbore. An ideal friction loss factor for a wellbore may refer to one or more values that represent the amount of ideal frictional pressure drop in the wellbore. The value of the ideal friction loss factor for a wellbore may reflect/correspond to the value of the ideal frictional pressure drop in the wellbore.

[0055] The ideal friction loss factor for the wellbore may be determined based on the ideal frictional pressure drop in the wellbore, the flow rate through the wellbore, and/or other information. The ideal friction loss factor for the wellbore may be determined using a relationship between the ideal frictional pressure drop in the wellbore and the flow rate through the wellbore. For example, the ideal friction loss factor (FLideai) for the wellbore may be determined as a ratio of the ideal frictional pressure drop (APideai) and the wellbore to the flow rate (Q) squared, such as:

[0056] The wellbore deposition indicator component 114 may be configured to determine a wellbore deposition indicator value. Determining a wellbore deposition indicator value include ascertaining, approximating, calculating, establishing, estimating, finding, identifying, obtaining, quantifying, selecting, setting, and/or otherwise determining the wellbore deposition indicator value. A wellbore deposition indicator value may refer to a value that indicates (e.g., reflects, corresponds to, characterizes) wellbore deposition. A wellbore deposition indicator value may refer to a value that indicates the amount and/or type of materials that have built up on the walls of the wellbore.

[0057] The wellbore deposition indicator value may be determined based on the measured friction loss factor, the ideal friction loss factor, and/or other information. The wellbore deposition indicator value may be determined using a relationship between the measured friction loss factor and the ideal friction loss factor. For example, the wellbore deposition indicator value (WDI) may be determined as a ratio of the measured friction loss factor and the ideal friction loss factor, such as:

WDI ⁼ FLmeasured / FLideai

[0058] In some implementations, the determination of the wellbore deposition indicator value as a ratio of the measured friction loss factor and the ideal friction loss factor may include calculation of the wellbore deposition indicator value as a ratio of the measured frictional pressure drop and the ideal frictional pressure drop in the wellbore:

WDI ⁼ AP measured / APideai

[0059] The wellbore deposition indicator value may include a single dimensionless parameter that may be used to monitor wellbore deposition. The wellbore deposition indicator value may capture the amount and/or type of materials that have built up on the wellbore. The wellbore deposition indicator value may capture the effects of changes/differences in wellbore operating characteristics, such as changing temperature, pressure, composition, and flow rate of the wellbore.

[0060] The wellbore deposition indicator value may include a single dimensionless parameter that standardizes monitoring of wellbore deposition across different wellbores. The wellbore deposition indicator value may enable monitoring of wellbore deposition that is decoupled from the changes/differences in the wellbore operating characteristics. Different wellbores may refer to wellbores in different locations, wellbores in different reservoirs, and/or wellbores with different operating characteristics. For example, different wellbores may refer to wellbores with different physical configurations or wellbores including different fluids. In some implementations, different wellbores may refer to the same wellbore that is operating with different operating characteristics at different times. The wellbore deposition indicator values for different wellbores may enable direct comparison of wellbore deposition across different wellbores. The wellbore deposition indicator values for different wellbores may enable direct comparison of wellbore deposition across different regions of earth (e.g., different reservoirs).

[0061]The deposition monitoring component 116 may be configured to facilitate deposition monitoring for the wellbore. Deposition monitoring for a wellbore may refer to monitoring of deposition on the walls of the wellbore. Deposition monitoring for a wellbore may refer to monitoring the existence, amount, rate, and/or type of material buildup on the walls of the wellbore. The deposition monitoring for the wellbore may be performed based on the wellbore deposition indicator value and/or other information. The wellbore deposition indicator value at a particular moment and/or the wellbore deposition indicator value at different moments in time (e.g., trend of wellbore deposition indicator value over time) may be used to determine whether materials have built up on the wellbore, the amount of materials that have built up on the wellbore, the rate at which materials are building up on the wellbore, and/or the type of materials that are building up on the wellbore. [0062] The deposition monitoring component 116 may facilitate the use of the wellbore deposition indicator value to perform deposition monitoring for the wellbore. The deposition monitoring component 116 may facilitate the use of information relating to and/or determined from the wellbore deposition indicator value to perform deposition monitoring for the wellbore. For example, facilitating deposition monitoring for the wellbore may include (1) presenting the wellbore deposition indicator value on the display 14, (2) presenting information relating to and/or determined from the wellbore deposition indicator value on the display 14, (3) presenting results of deposition monitoring for the wellbore on the display 14, (4) providing information relating to and/or determined from the wellbore deposition indicator value to one or more deposition monitoring processes, and/or (5) performing deposition monitoring for the wellbore using information relating to and/or determined from the wellbore deposition indicator value.

[0063] In some implementations, facilitation of the deposition monitoring for the wellbore based on the wellbore deposition indicator value may include generation of one or more plots. The plots may show changes in the plotted value over time. For example, a plot of the measured friction loss factor over time may be generated. The plot of the measured friction loss factor over time may show changes in the measured friction loss factor over time as the amount and/or type of deposit on the wellbore changes over time. A plot of the wellbore deposition indicator value over time may be generated. The plot of the wellbore deposition indicator value over time may show changes in the wellbore deposition indicator value over time as the amount and/or type of deposit on the wellbore changes over time.

[0064] In some implementations, one or more threshold values may be overlaid on top of one or more of the plots. The overlaying of the threshold value(s) may enable status of the wellbore deposition to be determined via comparison of the plot value (e.g., measured friction loss factor, wellbore deposition indicator value) to the threshold value(s). For example, a threshold value that separates significant deposits (e.g., amount of deposits on the wellbore that warrant use of remedial measures, amount of deposits of the wellbore that have sufficient impact on wellbore operation to warrant change in how the wellbore is used) from insignificant deposits may be overlaid on top of the plot of the wellbore deposition indicator value over time. Use of other threshold values is contemplated.

[0065] In some implementations, facilitation of the deposition monitoring for the wellbore based on the wellbore deposition indicator value may include monitoring of an amount of deposit formation on the wellbore using the wellbore deposition indicator value and/or other information. That wellbore deposition indicator value may be used as a value that represent the amount of deposit that have built up on the wellbore. An increase in the wellbore deposition indicator value may indicate that the amount of deposit that have built up on the wellbore has increased while a decrease in the wellbore deposition indicator value may indicate that the amount of deposit that have built up on the wellbore has decreased. The wellbore deposition indicator value over time may be used to determine the rate of wellbore deposition over time. In some implementations, the plot of wellbore deposition indicator value over time may show a trend (a profile) of wellbore deposition over time. In some implementations, the trend of wellbore deposition over time may be used to identify one or more characteristics about the deposits (e.g., types of deposits, formation characteristics) that have formed on the wellbore. For example, plateauing of the wellbore deposition indicator value over time may indicate that wellbore deposition may stop once the deposits have reached a certain thickness.

[0066] In some implementations, facilitation of the deposition monitoring for the wellbore based on the wellbore deposition indicator value may include determination of effectiveness of one or more deposition preventative measures to inhibit deposit formation on the wellbore using the wellbore deposition indicator value and/or other information. A deposition preventative measure may refer to one or more steps taken to prevent (e.g., not allow, reduce the likelihood or, reduce the amount of) wellbore deposition. For example, the wellbore may be made of materials that prevent wellbore deposition and/or the wellbore may be treated with materials to prevent wellbore deposition. The effectiveness of the deposition preventative measure(s) may be determined by monitoring the wellbore deposition indicator value for the wellbore in which the deposition preventative measure(s) have been applied. The effectiveness of the deposition preventative measure(s) may be determined by comparing the wellbore deposition indicator value for the wellbore in which the deposition preventative measure(s) have been applied to the wellbore deposition indicator value for the wellbore in which the deposition preventative measure(s) have not been applied.

[0067] In some implementations, facilitation of the deposition monitoring for the wellbore based on the wellbore deposition indicator value may include determination of effectiveness of one or more deposition remedial measures to remove deposit formation from the wellbore using the wellbore deposition indicator value and/or other information. A depositional remedial measure may refer to one or more steps taken to remove (e.g., eliminate, reduce the amount of) wellbore deposition. For example, physical and/or chemical/solvent processes may be applied to the wellbore to remove the materials that have built up on the wellbore. The effectiveness of the deposition remedial measure(s) may be determined by monitoring the wellbore deposition indicator value for the wellbore in which the deposition remedial measure(s) have been applied. The effectiveness of the deposition remedial measure(s) may be determined by comparing the wellbore deposition indicator value before and after the deposition remedial measure(s) have been applied to the wellbore. The effectiveness of the deposition remedial measure(s) may be determined by comparing the wellbore deposition indicator value for the wellbore in which the deposition remedial measure(s) have been applied to the wellbore deposition indicator value for the wellbore in which the deposition remedial measure(s) have not been applied.

[0068] In some implementations, facilitation of the deposition monitoring for the wellbore based on the wellbore deposition indicator value may include determination of deposit breakaway from the wellbore using the wellbore deposition indicator value and/or other information. Deposit breakaway from a wellbore may refer to when materials that have built up on the wellbore break away (e.g., completely, in parts) from the wellbore. Determination of deposit breakaway from the wellbore may include determination of when the deposit breakaway has occurred. For example, a sudden decrease in the wellbore deposition indicator value (e.g., decrease in the wellbore deposition indicator value at a rate greater than a threshold rate) may indicate that deposit breakaway has occurred. Determination of deposit breakaway from the wellbore may include prediction of when the deposit breakaway will occur. The amount and/or type of deposits on the wellbore (as determined from the wellbore deposition indicator value) may be used to predict when the deposit breakaway will occur. The deposit breakaway prediction may be determined further based on one or more operating characteristics of the wellbore. The prediction of deposit breakaway from the wellbore may be used to change wellbore operating characteristics (e.g., reduce or increase the likelihood of deposit breakaway). The prediction of deposit breakaway from the wellbore may be used to predict when material movement through the wellbore will occur (e.g., predict when solids will move though the choke of the wellbore).

[0069] FIG. 4 illustrates example changes in measured friction loss factor and wellbore deposition indicator value. FIG. 4 includes a plot of measured friction loss factor 400 and a plot of wellbore deposition indicator value 450. The plots 400, 450 shows changes in the measured friction loss factor and the wellbore deposition indicator value for a wellbore over time as solid lines. The dots on the plots 400, 450 may indicate measured friction loss factor and the wellbore deposition indicator value at different times and the solid lines may be curves fitted to the dots. When the wellbore deposition indicator value is close to one (e.g., within a threshold value of one), the wellbore may be clean. When the wellbore deposition indicator value is much greater than one (e.g., greater than a set multiple of one), the wellbore may have enough deposit to reduce production through the wellbore.

[0070] A threshold value that separates significant deposits from insignificant deposits is overlaid on the plot 450 as a dashed horizontal line. When the solid line is below the threshold value, the amount of deposition on the wellbore may be insignificant. When the solid line is above the threshold value, the amount of deposition on the wellbore may be significant. The threshold value in the plot 450 may have a value of 5. Use of other threshold value is contemplated.

[0071] Deposition remedial measures that have been applied to the wellbore at different times are shown as dotted vertical lines in the plots 400, 450. The effectiveness of the deposition remedial measures may be determined by comparing values of the plots 400, 450 before and after the deposition remedial measures have been applied.

[0072] Implementations of the disclosure may be made in hardware, firmware, software, or any suitable combination thereof. Aspects of the disclosure may be implemented as instructions stored on a machine-readable medium, which may be read and executed by one or more processors. A machine-readable medium may include any mechanism for storing or transmitting information in a form readable by a machine (e.g., a computing device). For example, a tangible computer-readable storage medium may include read-only memory, random access memory, magnetic disk storage media, optical storage media, flash memory devices, and others, and a machine-readable transmission media may include forms of propagated signals, such as carrier waves, infrared signals, digital signals, and others. Firmware, software, routines, or instructions may be described herein in terms of specific exemplary aspects and implementations of the disclosure, and performing certain actions.

[0073] In some implementations, some or all of the functionalities attributed herein to the system 10 may be provided by external resources not included in the system 10. External resources may include hosts/sources of information, computing, and/or processing and/or other providers of information, computing, and/or processing outside of the system 10.

[0074] Although the processor 11 , the electronic storage 13, and the display 14 are shown to be connected to the interface 12 in FIG. 1 , any communication medium may be used to facilitate interaction between any components of the system 10. One or more components of the system 10 may communicate with each other through hard-wired communication, wireless communication, or both. For example, one or more components of the system 10 may communicate with each other through a network. For example, the processor 11 may wirelessly communicate with the electronic storage 13. By way of non-limiting example, wireless communication may include one or more of radio communication, Bluetooth communication, Wi-Fi communication, cellular communication, infrared communication, or other wireless communication. Other types of communications are contemplated by the present disclosure.

[0075] Although the processor 11 , the electronic storage 13, and the display 14 are shown in FIG. 1 as single entities, this is for illustrative purposes only. One or more of the components of the system 10 may be contained within a single device or across multiple devices. For instance, the processor 11 may comprise a plurality of processing units. These processing units may be physically located within the same device, or the processor 11 may represent processing functionality of a plurality of devices operating in coordination. The processor 11 may be separate from and/or be part of one or more components of the system 10. The processor 11 may be configured to execute one or more components by software; hardware; firmware; some combination of software, hardware, and/or firmware; and/or other mechanisms for configuring processing capabilities on the processor 11 .

[0076] It should be appreciated that although computer program components are illustrated in FIG. 1 as being co-located within a single processing unit, one or more of computer program components may be located remotely from the other computer program components. While computer program components are described as performing or being configured to perform operations, computer program components may comprise instructions which may program processor 11 and/or system 10 to perform the operation.

[0077] While computer program components are described herein as being implemented via processor 11 through machine-readable instructions 100, this is merely for ease of reference and is not meant to be limiting. In some implementations, one or more functions of computer program components described herein may be implemented via hardware (e.g., dedicated chip, field-programmable gate array) rather than software. One or more functions of computer program components described herein may be software-implemented, hardware- implemented, or software and hardware-implemented.

[0078] The description of the functionality provided by the different computer program components described herein is for illustrative purposes, and is not intended to be limiting, as any of computer program components may provide more or less functionality than is described. For example, one or more of computer program components may be eliminated, and some or all of its functionality may be provided by other computer program components. As another example, processor 11 may be configured to execute one or more additional computer program components that may perform some or all of the functionality attributed to one or more of computer program components described herein.

[0079] The electronic storage media of the electronic storage 13 may be provided integrally (/.e., substantially non-removable) with one or more components of the system 10 and/or as removable storage that is connectable to one or more components of the system 10 via, for example, a port (e.g., a USB port, a Firewire port, etc.) or a drive (e.g., a disk drive, etc.). The electronic storage 13 may include one or more of optically readable storage media (e.g., optical disks, etc.), magnetically readable storage media (e.g., magnetic tape, magnetic hard drive, floppy drive, etc.), electrical charge-based storage media (e.g., EPROM, EEPROM, RAM, etc.), solid-state storage media (e.g., flash drive, etc.), and/or other electronically readable storage media. The electronic storage 13 may be a separate component within the system 10, or the electronic storage 13 may be provided integrally with one or more other components of the system 10 (e.g., the processor 11). Although the electronic storage 13 is shown in FIG. 1 as a single entity, this is for illustrative purposes only. In some implementations, the electronic storage 13 may comprise a plurality of storage units. These storage units may be physically located within the same device, or the electronic storage 13 may represent storage functionality of a plurality of devices operating in coordination.

[0080] FIG. 2 illustrates method 200 for monitoring wellbore deposition. The operations of method 200 presented below are intended to be illustrative. In some implementations, method 200 may be accomplished with one or more additional operations not described, and/or without one or more of the operations discussed. In some implementations, two or more of the operations may occur substantially simultaneously. [0081] In some implementations, method 200 may be implemented in one or more processing devices (e.g., a digital processor, an analog processor, a digital circuit designed to process information, a central processing unit, a graphics processing unit, a microcontroller, an analog circuit designed to process information, a state machine, and/or other mechanisms for electronically processing information). The one or more processing devices may include one or more devices executing some or all of the operations of method 200 in response to instructions stored electronically on one or more electronic storage media. The one or more processing devices may include one or more devices configured through hardware, firmware, and/or software to be specifically designed for execution of one or more of the operations of method 200.

[0082] Referring to FIG. 2 and method 200, at operation 202, flow rate information for a wellbore may be obtained. The flow rate information may define a flow rate through the wellbore. In some implementation, operation 202 may be performed by a processor component the same as or similar to the flow rate information component 102 (Shown in FIG. 1 and described herein).

[0083] At operation 204, measured pressure drop information for the wellbore may be obtained. The measured pressure drop information may define a measured frictional pressure drop in the wellbore. In some implementation, operation 204 may be performed by a processor component the same as or similar to the measured pressure drop information component 104 (Shown in FIG. 1 and described herein).

[0084] At operation 206, operating information for the wellbore may be obtained. The operating information may define operating characteristics of the wellbore. In some implementation, operation 206 may be performed by a processor component the same as or similar to the operating information component 106 (Shown in FIG. 1 and described herein).

[0085] At operation 208, an ideal frictional pressure drop in the wellbore may be determined based on the operating characteristics of the wellbore. In some implementation, operation 208 may be performed by a processor component the same as or similar to the ideal frictional pressure drop component 108 (Shown in FIG. 1 and described herein).

[0086]At operation 210, a measured friction loss factor for the wellbore may be determined based on the measured frictional pressure drop in the wellbore and the flow rate through the wellbore. In some implementation, operation 210 may be performed by a processor component the same as or similar to the measured friction loss factor component 110 (Shown in FIG. 1 and described herein).

[0087] At operation 212, an ideal friction loss factor for the wellbore may be determined based on the ideal frictional pressure drop in the wellbore and the flow rate through the wellbore. In some implementation, operation 212 may be performed by a processor component the same as or similar to the ideal friction loss factor component 112 (Shown in FIG. 1 and described herein).

[0088]At operation 214, a wellbore deposition indicator value may be determined based on the measured friction loss factor and the ideal friction loss factor. In some implementation, operation 214 may be performed by a processor component the same as or similar to the wellbore deposition indicator component 114 (Shown in FIG. 1 and described herein).

[0089]At operation 216, deposition monitoring for the wellbore based on the wellbore deposition indicator value may be facilitated. In some implementation, operation 216 may be performed by a processor component the same as or similar to the deposition monitoring component 116 (Shown in FIG. 1 and described herein).

[0090] Although the system(s) and/or method(s) of this disclosure have been described in detail for the purpose of illustration based on what is currently considered to be the most practical and preferred implementations, it is to be understood that such detail is solely for that purpose and that the disclosure is not limited to the disclosed implementations, but, on the contrary, is intended to cover modifications and equivalent arrangements that are within the spirit and scope of the appended claims. For example, it is to be understood that the present disclosure contemplates that, to the extent possible, one or more features of any implementation can be combined with one or more features of any other implementation.

T1

Claims

What is claimed is:

1 . A method for monitoring wellbore deposition, the method comprising: obtaining flow rate information for a wellbore, the flow rate information defining a flow rate through the wellbore; obtaining measured pressure drop information for the wellbore, the measured pressure drop information defining a measured frictional pressure drop in the wellbore; obtaining operating information for the wellbore, the operating information defining operating characteristics of the wellbore; determining an ideal frictional pressure drop in the wellbore based on the operating characteristics of the wellbore; determining a measured friction loss factor for the wellbore based on the measured frictional pressure drop in the wellbore and the flow rate through the wellbore; determining an ideal friction loss factor for the wellbore based on the ideal frictional pressure drop in the wellbore and the flow rate through the wellbore; determining a wellbore deposition indicator value based on the measured friction loss factor and the ideal friction loss factor; and facilitating deposition monitoring for the wellbore based on the wellbore deposition indicator value.

2. The method of claim 1 , wherein the wellbore deposition indicator value is determined as a ratio of the measured friction loss factor and the ideal friction loss factor.

3. The method of claim 1 , wherein facilitating the deposition monitoring for the wellbore based on the wellbore deposition indicator value includes monitoring of an amount of deposit formation on the wellbore using the wellbore deposition indicator value.

4. The method of claim 1 , wherein facilitating the deposition monitoring for the wellbore based on the wellbore deposition indicator value includes determining effectiveness of a deposition preventative measure to inhibit deposit formation on the wellbore using the wellbore deposition indicator value.

5. The method of claim 1 , wherein facilitating the deposition monitoring for the wellbore based on the wellbore deposition indicator value includes determining effectiveness of a deposition remedial measure to remove deposit formation from the wellbore using the wellbore deposition indicator value.

6. The method of claim 1 , wherein facilitating the deposition monitoring for the wellbore based on the wellbore deposition indicator value includes determining deposit breakaway from the wellbore using the wellbore deposition indicator value.

7. The method of claim 1 , wherein facilitating the deposition monitoring for the wellbore based on the wellbore deposition indicator value includes generating a plot of the wellbore deposition indicator value over time.

8. The method of claim 7, wherein a threshold value that separates significant deposits from insignificant deposits is overlaid on top of the plot of the wellbore deposition indicator value over time.

9. The method of claim 1, wherein the measured frictional pressure drop in the wellbore is determined based on a difference between a measured pressure drop in the wellbore and a hydrostatic pressure drop in the wellbore.

10. The method of claim 1 , wherein the wellbore deposition indicator value includes a dimensionless parameter that standardizes monitoring of wellbore deposition across different wellbores.

11. A system for monitoring wellbore deposition, the system comprising: one or more physical processors configured by machine-readable instructions to: obtain flow rate information for a wellbore, the flow rate information defining a flow rate through the wellbore; obtain measured pressure drop information for the wellbore, the measured pressure drop information defining a measured frictional pressure drop in the wellbore; obtain operating information for the wellbore, the operating information defining operating characteristics of the wellbore; determine an ideal frictional pressure drop in the wellbore based on the operating characteristics of the wellbore; determine a measured friction loss factor for the wellbore based on the measured frictional pressure drop in the wellbore and the flow rate through the wellbore; determine an ideal friction loss factor for the wellbore based on the ideal frictional pressure drop in the wellbore and the flow rate through the wellbore; determine a wellbore deposition indicator value based on the measured friction loss factor and the ideal friction loss factor; and facilitate deposition monitoring for the wellbore based on the wellbore deposition indicator value.

12. The system of claim 11 , wherein the wellbore deposition indicator value is determined as a ratio of the measured friction loss factor and the ideal friction loss factor.

13. The system of claim 11 , wherein facilitation of the deposition monitoring for the wellbore based on the wellbore deposition indicator value includes monitoring of an amount of deposit formation on the wellbore using the wellbore deposition indicator value.

14. The system of claim 11 , wherein facilitation of the deposition monitoring for the wellbore based on the wellbore deposition indicator value includes determination of effectiveness of a deposition preventative measure to inhibit deposit formation on the wellbore using the wellbore deposition indicator value.

15. The system of claim 11 , wherein facilitation of the deposition monitoring for the wellbore based on the wellbore deposition indicator value includes determination of effectiveness of a deposition remedial measure to remove deposit formation from the wellbore using the wellbore deposition indicator value.