EP3284903A1 - Systeme und verfahren zum simulieren von zementplatzierung - Google Patents

Systeme und verfahren zum simulieren von zementplatzierung Download PDF

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Publication number
EP3284903A1
EP3284903A1 EP16306066.8A EP16306066A EP3284903A1 EP 3284903 A1 EP3284903 A1 EP 3284903A1 EP 16306066 A EP16306066 A EP 16306066A EP 3284903 A1 EP3284903 A1 EP 3284903A1
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EP
European Patent Office
Prior art keywords
wellbore
fluid
wellbore fluid
annulus space
cement
Prior art date
Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
Withdrawn
Application number
EP16306066.8A
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English (en)
French (fr)
Inventor
Nicolas C.G.L. FLAMANT
Philippe M J Tardy
Andrew J. Parry
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
Services Petroliers Schlumberger SA
Schlumberger Technology BV
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Services Petroliers Schlumberger SA
Schlumberger Technology BV
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
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Publication date
Application filed by Services Petroliers Schlumberger SA, Schlumberger Technology BV filed Critical Services Petroliers Schlumberger SA
Priority to EP16306066.8A priority Critical patent/EP3284903A1/de
Priority to PCT/EP2017/000938 priority patent/WO2018033234A1/en
Publication of EP3284903A1 publication Critical patent/EP3284903A1/de
Withdrawn legal-status Critical Current

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    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B47/00—Survey of boreholes or wells
    • E21B47/10—Locating fluid leaks, intrusions or movements
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B33/00—Sealing or packing boreholes or wells
    • E21B33/10—Sealing or packing boreholes or wells in the borehole
    • E21B33/13—Methods or devices for cementing, for plugging holes, crevices or the like
    • E21B33/14—Methods or devices for cementing, for plugging holes, crevices or the like for cementing casings into boreholes
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B47/00—Survey of boreholes or wells
    • E21B47/005—Monitoring or checking of cementation quality or level

Definitions

  • This disclosure relates to the placement of cement within an annular space of a wellbore and, more particularly, to simulating the placement of the cement within the annular space of the wellbore.
  • a wellbore drilled into a geological formation may be targeted to produce hydrocarbons from certain zones of the geological formation.
  • the wellbore may be completed by placing a cylindrical casing into the wellbore and cementing the annulus between the casing and the wall of the wellbore. During cementing, cement may be injected into the annulus formed between the cylindrical casing and the geological formation. When the cement properly sets, fluids from one zone of the geological formation may not be able to pass through the wellbore to interact with one another. This desirable condition is referred to as "zonal isolation.”
  • Yet well completions may not go as planned. For example, the cement may not set as planned and/or the quality of the cement may be different than expected. In other cases, the cement may unexpectedly fail to set above a certain depth due to natural fissures in the formation.
  • a variety of individual simulators or modeling tools may be used to simulate various individual properties regarding the placement of cement within an annular space of a wellbore. Although each individual simulator may provide some insight on determining how the cement should be pumped into the annular space, each individual simulator may not account for the results of other simulations to accurately determine how the cement is expected to behave (e.g., dry) when placed within the annular space, an amount of pressure that is to maintained within the well bore to avoid fracturing an adjacent formation, a predicted temperature of the cement that may influence settling of the cement, how various fluids may mix with each other when the cement is being pumped into the annular space, and the like.
  • each individual simulator may provide some insight on determining how the cement should be pumped into the annular space
  • each individual simulator may not account for the results of other simulations to accurately determine how the cement is expected to behave (e.g., dry) when placed within the annular space, an amount of pressure that is to maintained within the well bore to avoid fracturing an adjacent formation, a predicted temperature of the
  • a method may include receiving, via one or more processors, data related to a wellbore fluid, a wellbore, and a geological formation. The method may then include determining one or more properties associated with the wellbore fluid over a simulated period of time when the wellbore fluid is to be pumped into an annulus space of the wellbore based at least in part on the data.
  • the method may then determine one or more temperature values associated with the wellbore fluid over the simulated period of time based at least in part on the data and the one or more properties associated with the wellbore fluid; determine an expected three-dimensional shape of the annulus space based at least in part on the data, the one or more properties associated with the wellbore fluid, and the one or more temperature values; and determine one or more bottom-hole fluid properties associated with the wellbore fluid over the simulated period of time based at least in part on the properties of the wellbore fluid and at least a portion of the one or more temperature values.
  • the method may then generate a wellbore fluid placement map associated with the annulus space based on the one or more bottom-hole fluid properties, the three-dimensional shape of the annulus space, and the one or more temperature values, wherein the wellbore fluid placement map comprises one or more expected concentration levels of the wellbore fluid within the annulus space after the simulated period of time expires.
  • one or more tangible, non-transitory computer-readable media comprising instructions configured to cause at least one processor to receive data related to a wellbore fluid, a wellbore, and a geological formation.
  • the at least one processor may then simulate a cement installation workflow for an annulus space of the wellbore based at least partly on the received data using a plurality of simulators to obtain a wellbore fluid placement map of cement placement that is expected to occur when the cement installation workflow is carried out.
  • At least two of the plurality of simulators use a respective output from the at least two of the plurality of simulators to perform a respective operation of the at least two of the plurality of simulators.
  • a computer-implemented method for simulating a fluid placement operation to obtain a fluid placement map may include performing a hydraulics simulation of a wellbore for a fluid placement operation to obtain simulated displacements of one or more fluids within an annulus space of the wellbore during the fluid placement operation based on a hydraulics model of the one or more fluids.
  • the computer-implemented method may then perform a temperature simulation of the wellbore for the fluid placement operation to obtain a simulated temperature profile within the wellbore, such that the temperature simulation is based at least in part on the simulated displacements of the fluids, and the hydraulics simulation is based at least in part on the simulated temperature profile within the wellbore.
  • the computer-implemented method may then perform a centralization simulation of the wellbore to obtain an expected three-dimensional annulus shape of the annulus space based on the simulated temperature profile and the one or more simulated displacements.
  • the computer-implemented method may also perform a pipe placement simulation of the wellbore to obtain one or more bottom-hole properties associated with the fluids based on the simulated temperature profile and the one or more simulated displacements.
  • the computer-implemented method may also perform an annular displacement simulation of the wellbore to obtain a fluid placement map indicating one or more concentration levels of the fluids within the annulus space after the fluid placment operation has been performed based on the expected three-dimensional annulus shape and the one or more bottom-hole properties.
  • metal casing When a well is drilled, metal casing may be installed inside the well and cement placed into the annulus between the casing and the wellbore. When the cement sets, fluids from one zone of the geological formation may not be able to pass through the annulus of the wellbore to interact with another zone. This desirable condition is referred to as "zonal isolation.” Proper cement installation may also ensure that the well produces from targeted zones of interest.
  • Embodiments of this disclosure relate to various systems, methods, and devices for efficiently generating a workflow or design for forming an annular ring within a wellbore using wellbore fluids, such as cement, cement slurry, drilling fluids or muds, completion fluids or muds, workover fluids or muds, and the like.
  • wellbore fluids such as cement, cement slurry, drilling fluids or muds, completion fluids or muds, workover fluids or muds, and the like.
  • the systems, methods, and devices of this disclosure describe various ways of generating an expected cement slurry placement map within a wellbore based on various properties of the fluids pumped into the wellbore to properly place the cement within the annular space, the temperature of the cement slurry as it is pumped into the annular space, a position of a case string while the cement is pumped into the annular space, a position of a pipe within the wellbore, and the like.
  • the expected cement slurry placement map may thus be determined based on a number of simulators; however, the order and manner in which each simulator is performed may prove to efficiently determine the expected cement slurry placement map for a particular cement job design.
  • FIG. 1 schematically illustrates a system 10 for placing cement within an annular space of a well.
  • FIG. 1 illustrates surface equipment 12 above a geological formation 14.
  • a drilling operation has previously been carried out to drill a wellbore 16.
  • a casing string 18 may be positioned.
  • an annulus space 20 may be present, such that cement may be injected into the annulus space 20 to create a cement sheath between the casing string 18 and the geological formation 14.
  • the cement sheath may provide a hydraulic seal that establishes zonal isolation that may prevent fluid communication between producing zones within the wellbore 16 and may block the escape of fluids to the surface.
  • the cement sheath may also anchor and support the casing string 18 and protect other casing (e.g., steel casing) against corrosion due to contact with formation fluids.
  • the bottom end of the casing string 18 may include a shoe 22.
  • the shoe 22 may be a guide shoe or a float shoe. In either case, the shoe 22 may be a device that guides the casing string 18 toward the center of the wellbore 16 to minimize contact with rough edges or washouts during installation.
  • centralizers 24 may be placed within the annulus space 20 to prevent the casing string 18 from sticking while it is lowered into the wellbore 16. The centralizers 24 also help keep the casing string 18 in the center of the wellbore 16 to help ensure placement of a uniform cement sheath in the annulus space 20.
  • a cementing operation includes removing the drilling fluid from the interior of the casing string 18, placing a cement slurry in an annulus, and filling the interior of the casing string 18 with a displacement fluid, such as a drilling fluid, brine, or water.
  • the system 10 may include surface equipment 26 that may carry out a cement installation operation, various well logging operations to detect conditions of the wellbore 16, and the like.
  • the cement operation may generally refer to the process of pumping cement into the wellbore 16 to form an annular ring of cement between the casing string 18 and the geological formation 14.
  • the surface equipment 26 may include equipment that store cement slurries, drilling fluids, displacement fluids, spacer fluids, chemical wash fluids, and the like.
  • the surface equipment 26 may include piping and other materials used to transport the various fluids described above into the wellbore 16.
  • the surface equipment 26 may also include pumps and other equipment (e.g., batch mixers, centrifugal pumps, liquid additive metering systems, tanks, etc.) that may fill in the interior of the casing string 18 with the fluids discussed above.
  • cement slurry may force the drilling fluid out of the casing interior via the shoe 22 and up the annulus space 20 until the bottom plug lands at the bottom of the casing string 18.
  • the bottom plug may include a membrane that ruptures when the bottom plug reaches the bottom of the casing string 18. As such, the bottom plug may now have a pathway form the cement slurry to enter the annulus space 20 via the membrane of the bottom plug after the bottom plug reaches the bottom of the casing string 18.
  • a top plug (not shown) may then be placed on top of the cement slurry followed by displacement fluid. The displacement fluid may then be pumped into the interior of the casing string 18 forcing the cement slurry into the annulus space 20 until the top plug reaches the bottom plug, thereby isolating the interior of the casing string 18 from the slurry within the annulus space 20.
  • the slurry may take time to cure.
  • the cured cement may then be evaluated using certain logging tools to ensure that the cement placed within the annulus space 20 is robust and capable of maintaining a threshold stress between the casing string 18 and the geological formation 14. That is, after the cement has set, the cement should withstand stress and be a hydraulics barrier to prevent any formation fluid (e.g., gas) flow through the cement.
  • formation fluid e.g., gas
  • the cement operation may be controlled by a data processing system 28 that includes a processor 30, memory 32, storage 34, and/or a display 36.
  • the processor 30 may include any suitable processor capable of executing computer-readable instructions (e.g., non-transitory). Moreover, it should be understood that the processor 30, in some embodiments, may include multiple processors operating in conjunction with each other.
  • the data processing system 28 may control the cement operation described above including the operation of the pumps, the placement of the plugs, the switching between various fluids, and the like. In addition, the data processing system 28 may evaluate the integrity of the cement annular ring after the cement operation is completed.
  • the data processing system 28 or any other suitable computing device may perform a design workflow or simulation of the cement operation prior to placing the cement within the wellbore 16. That is, the data processing system 28 may use one or more models or simulations to determine various parameters (e.g., amount of cement, displacement fluid, pressure to pump cement, size of plugs) to use when performing the 32 and/or storage 34.
  • the memory 32 and/or the storage 34 of the data processing system 28 may be any suitable article of manufacture that can store the instructions.
  • the memory 32 and/or the storage 34 may be ROM memory, random-access memory (RAM), flash memory, an optical storage medium, or a hard disk drive, to name a few examples.
  • the display 36 may be any suitable electronic display that can display a cement slurry placement map, expected parameters for performing the cement operation, or the like.
  • drilling mud and cement slurry are both viscoplastic and exhibit a yield stress, these two fluids may remain unyielded in the narrow part of an eccentric portion of the annulus space 20, thus preventing the correct placement of the cement slurry.
  • drilling mud and slurry may have a different density leading to flow segregation whereby the lighter fluid flows at the top of the annulus, bypassing the heavier fluid lying at the bottom.
  • designing a cement operation may include assessing whether the drilling mud will be sufficiently removed from the annulus space 20 and the slurry will be correctly put in place within the annulus space 20.
  • the data processing system 28 may receive various types of information regarding the wellbore 16 (e.g., type of rock formation within the formation 14, depth of wellbore 16, properties of drilling mud, wellbore fluid, and other fluids, temperature within the wellbore 16, pressures within the wellbore 16) and generate a simulation or model that accounts for the effects of each of these types of information while the cement operation is being performed.
  • the wellbore 16 e.g., type of rock formation within the formation 14, depth of wellbore 16, properties of drilling mud, wellbore fluid, and other fluids, temperature within the wellbore 16, pressures within the wellbore 16
  • the data processing system 28 or any other suitable computing device may generate simulations for various attributes of the cement operation independently or according to a particular workflow, such that the simulations are generated in a practical manner within an acceptable amount of time to implement the determined design.
  • the data processing system 28 may use a cloud-based computing system 38 to assist performing the computations associated with generating the model or simulation of the cement operation.
  • the cloud-based computing system 38 may include a number of computers that may be connected through a real-time communication network, such as the Internet.
  • large-scale analysis operations may be distributed over the computers that make up the cloud-based computing system 38.
  • the computers or computing devices provided by the cloud-based computing system 38 may be dedicated to performing various types of complex and time-consuming analysis that may include analyzing a large amount of data and generating simulations and/or models described herein.
  • the data processing system efficiently uses various computing resources provided by the data processing system 28 or the like. That is, the presently disclosed workflow for generating a model of the cement operation and an expected wellbore fluid placement map provides an improvement in which the data processing system 28 or any other suitable computing device may perform the simulation or modeling operations of the cement operation. As such, the presently disclosed systems and techniques are directed to a specific implementation of a solution to a problem in the software arts related to efficiently generating a model or simulation of a cement operation that accounts for the complexities of a wellbore.
  • FIG. 2 illustrates a block diagram of a workflow 50 for using various types of simulators to determine an expected wellbore fluid placement map in accordance with embodiments described herein.
  • the workflow 50 will be discussed below as being performed by the data processing system 28, it should be noted that any suitable computing device may perform the workflow 50.
  • the data processing system 28 may initially receive information related to the location in which a cement annular ring may be built.
  • the data processing system 28 may receive wellbore, formation, equipment, and fluid properties 52, which may include various types of data regarding the wellbore 16, the formation 14, the equipment to be used for the cement operation, the various fluids that may be used for the cement operation and the like.
  • the data regarding the wellbore 16 may include details regarding the wellbore 16 including, for example, the depth of the wellbore 16, the temperature at various locations within the wellbore 16, the pressure values at various locations within the wellbore 16, and the like.
  • the data may include information from previous well logs regarding the wellbore 16 with regard to formation properties, well trajectory, density of the provided fluids, the viscosity of the provided fluids, and the like.
  • the data may include viscosity and/or rheology properties related to the fluids as measured by various surface equipment.
  • the data regarding the formation 14 may include the locations of various rock types or geological layers within the formation 14.
  • the data regarding the formation 14 may also include information related to the location of various hydrocarbon deposits, the existing fractures within the formation 14, and the like.
  • the data regarding the equipment may include information related to the types of equipment (e.g., capacity tank, pumps, storage equipment for both solids and liquids, blending equipment, mixers, metering equipment) that may be available to perform the cement operation.
  • the fluid information may include details related to the types of fluids (e.g., drilling fluid, chemical washout, wellbore fluid, displacement fluid) including, for example, the amount of fluid available, the temperature of the fluid, the viscosity of the fluid, the density of the fluid, and other relevant parameters that describe the properties of the various fluids used in the cement operation.
  • the fluid information may include a description of the fluids, which may include a density model, a viscosity model, and a multi-phase model.
  • the fluid information may be detailed with models because the respective modeled properties are not constant and usually change with time, pressure, temperature, fluid velocity, fluid contamination, and the like.
  • the multi-phase model may indicate an expected percentage of solid, water, and hydrocarbons that may make up a formation fluid.
  • the solids percentage may provide information regarding the particles size distribution within the fluid.
  • it may be useful to measure each of the above-listed properties at regular intervals at known conditions (e.g., pressure, temperature) and then use the properties as inputs to another model that may predict certain values related to the formation fluids under the conditions experienced in the well.
  • Additional data regarding the wellbore 16 may include a flow rate at which certain fluids are injected in the wellbore 16, a pressure at various surface pumps, a pressure at a wellhead (e.g., cement head), and the like.
  • a flow rate at which certain fluids are injected in the wellbore 16 may include a pressure at various surface pumps, a pressure at a wellhead (e.g., cement head), and the like.
  • a wellhead e.g., cement head
  • it may be useful to determine a starting point for the simulation based on, for example, a temperature profile in the wellbore 16 at t 0, fluid(s) in the well, properties of the fluids, and the like.
  • the hydraulics simulator 54 may include a one-dimensional simulator (e.g., hydraulics model) that assumes piston-like displacement of all of the fluids within the wellbore 16. Since the hydraulics simulator 54 is a one-dimensional simulator, it may assume a homogeneous azimuthal distribution. As such, the hydraulics simulator 54 may not indicate the azimuthal position of the cement slurry within the annulus space 20. However, the hydraulics simulator 54 may provide details regarding a location of each fluid within the wellbore 16 and the annulus space 20 during the cement operation assuming that different fluids are not mixed with each other.
  • a one-dimensional simulator e.g., hydraulics model
  • the output of the hydraulics simulator 54 may include fluid position with respect to time during the cement operation (e.g., down the flow patch and up the annulus space 20).
  • the hydraulics simulator 54 may also provide information related to the pressure of the fluid throughout the flow path with respect to time. As such, the hydraulics simulator 54 may determine whether the pressure in the annulus space 20 will remain above a pore pressure of the formation 14 and below a fracture pressure of the formation 14 during the cement operation.
  • the pressure information related to the fluids pumped into the annulus space 20, as well as the fluid position with respect to time, may then be output by the hydraulics simulator as expected fluid properties 60 of the fluids.
  • the hydraulics simulator 54 may also determine a dynamic length of an air gap, called u-tube (e.g., u-tube length 58), at the top of the casing string 18 that may occur due to hydrostatic imbalance between the casing string 18 and the annulus space 20. This imbalance may result from the density contrasts between the fluids present within the wellbore 16 during the cement operation.
  • the cement slurry may be denser than the drilling mud being displaced by the cement slurry.
  • a temperature simulator 56 may be coupled with the hydraulics simulator 54, such that the temperature simulator 56 may provide an expected temperature of each fluid type within the flow path of the wellbore 16 over a period of time associated with the cement operation.
  • the temperature simulator 56 may be coupled with the hydraulics simulator 54 in that at various time steps, the position of a particular fluid type (e.g., wellbore fluid, cement slurry) and the velocity of the fluid type may be provided to the temperature simulator 56 from the hydraulics simulator 54 (e.g., via the expected fluid properties 60). For instance, since fluid properties, such as density and rheology are a function of temperature, the temperature simulator 56 may use this information, as provided via the expected fluid properties 60, to determine the expected temperature of each fluid type throughout the course of the cement operation.
  • the output of the temperature simulator 56 may thus include a temperature profile 62 that details the expected temperature values of various fluid types employed during the cement operation with respect to time and the position of the respective fluid type within the flow path.
  • the hydraulics simulator 54 may also receive the temperature profile 62 output by the temperature simulator 56 and update its respective simulation to more accurately determine the expected fluid properties 60 and the u-tube length 58 during the course of the cement operation. As such, the hydraulics simulator 54 and the temperature simulator 56 may assist each other in determining how the cement slurry is behaving during the cement operation. In some embodiments, the hydraulics simulator 54 and the temperature simulator 56 may exchange relevant information upon completion of a respective iteration of the respective simulation. For instance, after the hydraulics simulator 54 completes one iteration and determines the expected fluid properties 60, the temperature simulator 56 may receive this information to determine the corresponding temperature profile 62 in one iteration.
  • the resulting temperature profile 62 may then be passed to the hydraulics simulator 54, which may perform an updated iteration of its respective simulation using the updated temperature profile 62.
  • Each iteration may be related to a time step and the iterative process may then continue for the expected duration of the cement operation.
  • the temperature simulator 56 may use the pressure data determined by the hydraulics simulator 54 and the hydraulics simulator 54 may use the temperature data determined by the temperature simulator 56.
  • the coupling between both simulators enables each respective simulator to output improved results.
  • the presently disclosed techniques may include iteratively determining the expected fluid properties 60 until the expected fluid properties 60 converge towards a stable solution.
  • various simulators described herein may be coupled together in a variety of techniques.
  • various simulators may be coupled to each other using linear coupling coefficients, such as the method described in U.S. Patent Application Publication No. 2013132050 , a functional mock-up interface (FMI), and the like.
  • a functional mock-up interface FMI is a standardized protocol to communicate between solvers (e.g., simulators) to carry out a coupled simulation between two or more simulators.
  • the coupled simulations can be carried out in a co-simulation mode with data being exchanged between functional mock-up units (FMU).
  • the first approach may be characterized as a strong coupling that uses an implicit time integration method, such that the fluid simulator and the structure simulator share results with each other to formulate respective outputs.
  • the second approach may be characterized as a weak coupling where the time integration method is classified as explicit, and the fluid simulator and structure simulator share results obtained from a previous time step. As a result, no iteration is used for the data exchange.
  • the data processing system 28 may input these datasets into a centralization simulator 64.
  • the centralization simulator 64 may provide a position of the casing string 18 within the wellbore 16 at a given time during the cement operation based on the expected number and positions of the centralizers 24 within the annulus space 20.
  • the centralization simulator 64 may use the centralizer information (e.g., number and position) and data related to fluids positions, the pressure profile in the flow path, the drag force profile in the flow path due to the flow, and the temperature in the casing string, acquired via the expected fluid properties 60 and the temperature profile 62, to determine an expected three-dimensional annulus shape 70 for the annulus space 20.
  • the centralization simulator 64 may be executed iteratively to determine a number and position for each centralizer that may be placed within the annulus space to achieve a specified (e.g., input) annulus shape of the annulus space 20 or an annulus shape that is within a threshold of the specified annulus shape.
  • a pipe displacement simulator 66 may be executed to determine bottom-hole fluid properties 68. That is, the pipe displacement simulator 66 may determine the properties of the fluid types as they pass through the shoe 22. Unlike the hydraulics simulator 54, the pipe displacement simulator 66 may not assume that the fluids in the wellbore 16 behave according to a piston-like displacement. As such, the pipe displacement simulator 66 may provide concentration profiles (e.g., the bottom-hole fluid properties 68) of the fluids within the casing at the shoe 22 as a function of depth and time.
  • concentration profiles e.g., the bottom-hole fluid properties 68
  • the pipe displacement simulator 66 may receive the u-tube length 58 and the temperature profile 62 information described above as inputs to determine fluids concentrations and flow rate with respect to time at the shoe 22 for the course of the cement operation. In this way, the pipe displacement simulator 66 may focus on the behavior of the fluids at the shoe 22 with respect to the u-tube length 58, as provided by the hydraulics simulator 54.
  • the data processing system 28 may provide these inputs, along with the temperature profile 62, to an annular displacement simulator 72.
  • the annular displacement simulator 72 may determine a cement slurry placement map 74 based on the full three-dimensional shape of the annulus (e.g., 3D annulus shape 70). That is, the annular displacement simulator 72 may account for the uneven flow of the slurry in the eccentric portion of the annulus space 120 that may be created due to the movement or lack of movement of the casing string 18 during the cement operation and the like.
  • the annular displacement simulator 72 may simulate or model how fluids may flow faster in the larger part of the annulus space 20 and sometimes remain unyielded in a narrow part of the annulus space 20.
  • by-passing of drilling mud may also be caused by fluid property contrasts such as rheology and density contrasts.
  • the annular displacement simulator 72 may also accounts for such effects in addition to handling the actual annulus geometry.
  • the annular displacement simulator 72 receives the 3D annulus shape 70, the bottom-hole fluid properties 68 (e.g., fluids concentrations and flow rate), and the temperature profile 62 (e.g., temperature within the annulus space 20) to determine how various fluid types may mix or move unevenly within the annulus space 20 during the cement operation.
  • the fluid mixing may then be propagated to the end of the simulation of the cement operation to determine a cement slurry placement or concentration map 74.
  • the cement slurry placement map 74 may detail the slurry volume fraction as a function of depth and azimuth. As such, the cement slurry placement map 74 may provide information regarding how well the cement will cure and will remain in place after being placed within the annulus space 20. Moreover, the cement slurry placement map 74 may account for the various fluids (e.g., drilling fluid, spacer fluid, mud) that may not have been removed from the annulus space 20 and may have instead mixed with the cement slurry and remained in the annulus space 20 after the cement has cured. As a result, the cement placement map 74 may enable the data processing system 28 to determine whether the cement operation would adequately maintain a threshold stress or hydraulic barrier between the casing string 18 and the formation 14, prevent formation fluids from moving within the annulus space 20, and the like.
  • various fluids e.g., drilling fluid, spacer fluid, mud
  • FIG. 3 illustrates an example cement slurry placement map 80 that details the concentration of levels of the slurry within the annulus space 20.
  • the vertical axis of the example cement slurry placement map 80 corresponds to a measured depth along the well bore 16 and the horizontal axis corresponds to the azimuthal distance around the annulus.
  • the annulus space 20 is primarily filled with slurry with near 100% concentration, as indicated in region 82.
  • various portions 84 within the cement slurry placement map 80 may indicate that the concentration of the slurry may be less than 100%.
  • the data processing system 28 may evaluate whether cement annular ring will sufficiently maintain a threshold stress level or hydraulic barrier between the formation 14 and the casing string 18. For instance, the data processing system 28 may use the cement slurry placement map 74 as an input into a structural finite element simulator to determine whether the annular cement ring will sustain the various stresses that may be placed on the annular cement ring during operation of the well (e.g., hydrocarbon production for the life of the well and after the well has been decommissioned).
  • additional inputs such as locations in which the formation 14 will be fractured, locations in which the annular cement ring may be perforated, and other structural parameters related to the annular cement ring that may change during the life of the well, may also be provided to the structural finite element simulator to determine whether the annular cement ring will sustain the various stresses that may be placed on the annular cement ring during operation of the well (e.g., hydrocarbon production for the life of the well).
  • the data processing system 28 may adjust various parameters of one or more of the simulators of the workflow 50 to improve the concentration levels of the cement slurry within the cement annular ring. For instance, the data processing system 28 may adjust the fluid properties of the fluids used during the cement operation, adjust the pump rates used during the cement operation, control the friction pressure drop, control the mixing of the fluids during the cement operation, and the like. In addition, the data processing system 28 may adjust the number and/or placement of the centralizers used in the centralization simulator 64 to improve the concentration levels of the cement slurry within the annular ring.
  • the workflow 50 may be performed in parallel with respect different input parameters (e.g., wellbore, formation, equipment, and fluid properties 52).
  • the data processing system 28 may identify a range of parameters that may be adjusted to improve the structural integrity of the resulting annular cement ring.
  • the data processing system 28 may specify the range of parameters to the cloud-based computing system 38.
  • the cloud-based computing system 38 may perform the workflow 50 for each parameter (or a portion of the parameters) of the identified range.
  • multiple cement slurry placement maps 74 may be generated in parallel and provided to the data processing system 28.
  • the data processing system 28 may then compare the generated cement slurry placement maps 74 with each other to identify which of the generated cement slurry placement maps 74 may be best suited for maintaining the threshold pressures or sustaining the expected stresses during the life of the well.

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GB2625033A (en) * 2021-12-14 2024-06-05 Halliburton Energy Services Inc System to correlate suitable slurry designs with petrophysical while-drilling measurements in real time

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