Patent Publication Number: US-2022229942-A1

Title: Hybrid collapase strength for borehole tubular design

Description:
TECHNICAL FIELD 
     This application is directed, in general, to tubular structure design for boreholes and, more specifically, to using a collapse strength for tubular structure designs. 
     BACKGROUND 
     When developing and drilling boreholes, it is important to be able to support the borehole against collapse, ensure borehole integrity, and protect equipment that is lowered into the borehole. In addition, the borehole may be exposed to varying temperatures, formation fluids, electromagnetic radiation, and varying types of minerology. These factors can adversely affect the equipment lowered into the borehole. Tubular structures, for example, casing or pipe, can assist in protecting the equipment, as well as in some aspects of supporting the borehole against formation leakage and collapse. It would be beneficial to improve the efficiency of the borehole design, by more accurately predicting the operational wear on the tubular structures used within the borehole. 
     SUMMARY 
     In one aspect a method is disclosed. In one embodiment, the method includes (1) receiving input parameters for a tubular structure design of a tubular structure of a borehole, wherein the tubular structure design utilizes a hybrid collapse strength model, (2) updating a wear allowance of the tubular structure, wherein an initial wall thickness of the tubular structure is updated to an adjusted wall thickness using the input parameters, (3) calculating a collapse rating utilizing the hybrid collapse strength model, the input parameters, and the wear allowance, wherein the hybrid collapse strength model includes a designated collapse strength model, and (4) computing a collapse safety factor utilizing the collapse rating. 
     In a second aspect a hybrid collapse strength modeler system is disclosed. In one embodiment, the hybrid collapse strength modeler system includes (1) a parameter receiver, capable to receive input parameters, (2) a result transceiver, capable of communicating result parameters, and (3) a wear allowance modeler, capable of utilizing the input parameters to determine one or more designated collapse strength models to apply to a tubular structure for a tubular structure design for a borehole, and to generate the result parameters. 
     In a third aspect a computer program product having a series of operating instructions stored on a non-transitory computer-readable medium that directs a data processing apparatus when executed thereby to perform operations is disclosed. In one embodiment, the operations include (1) receiving input parameters for a tubular structure design of a tubular structure of a borehole, wherein the tubular structure design utilizes a hybrid collapse strength model, (2) updating a wear allowance of the tubular structure, wherein an initial wall thickness of the tubular structure is updated to an adjusted wall thickness using the input parameters, (3) calculating a collapse rating utilizing the hybrid collapse strength model, the input parameters, and the wear allowance, wherein the hybrid collapse strength model includes a designated collapse strength model, and (4) computing a collapse safety factor utilizing the collapse rating. 
    
    
     
       BRIEF DESCRIPTION 
       Reference is now made to the following descriptions taken in conjunction with the accompanying drawings, in which: 
         FIG. 1  is an illustration of a diagram of an example drilling system; 
         FIG. 2  is an illustration of a diagram of an example wireline system; 
         FIG. 3  is an illustration of a diagram of an example offshore system; 
         FIG. 4  is an illustration of a diagram of an example hydraulic fracturing system; 
         FIG. 5  is an illustration of a diagram of an example graph showing a gap between the API 5C3 collapse strength model and a controlled test; 
         FIG. 6  is an illustration of a diagram of an example graph showing a hybrid collapse strength model; 
         FIG. 7  is an illustration of a flow diagram of an example method using a hybrid collapse strength model; 
         FIG. 8  is an illustration of a block diagram of an example hybrid collapse strength modeler system; and 
         FIG. 9  is an illustration of a block diagram of an example of a tubular structure design controller according to the principles of the disclosure. 
     
    
    
     DETAILED DESCRIPTION 
     When designing borehole systems, one factor to be considered is the type of tubular structures to be used in the borehole. During the operational lifetime of a borehole, tubular structures can be subject to combined damage caused by corrosion and mechanical wear. It is beneficial to conduct detailed stress analyses including the damage factors at the stage of tubular structure design. To ensure the tubular structure meets the operational goal, such as satisfying the operational lifetime of the borehole or another specified time interval, the estimated total amount of material loss or corrosion, e.g., metal loss or other material loss, can be compared against the determined maximum allowable wear, or a maximum allowable material loss, for a safety check of the design. 
     Tubular structures can vary as to the material used and the thickness of the wall of the tubular structure. The type of tubular structure used at a particular depth can be different than the tubular structure used in another portion of the borehole. During the design phase, it is beneficial to select a tubular structure that can maximize the efficiency of the borehole operations at a particular location within the borehole. 
     Additional cost can be incurred in replacing a section of the tubular structure if a portion or section of the tubular structure wears out sooner than planned. Wear on the tubular structure can occur due to various factors, for example, physical or mechanical wearing due to trip in or trip out of tools such as a wireline tool or a drill string, physical or mechanical wearing due to rotation of a drill string, corrosion factors, pressure factors, temperature factors, minerology factors, and other factors. 
     Typically, users design the tubular structures against various loads such as axial, burst, and collapse. Collapse design involves modeling and simulation of tubular structure collapse strength and tubular structure collapse loads. Conventionally, tubular structure collapse strength can be calculated using the American Petroleum Institute (API) bulletin 5C3 collapse strength model or another industry standards collapse strength model. In some aspects, the API 5C3 model may underestimate the collapse resistance of special-type high-collapse tubular structures. As a result, the tubular structure could be over-designed in terms of collapse, which is not cost effective for the borehole system. Tubular structures can be casing, tubing, drill strings, downhole tools, and other types of tubular structures. 
     The API 5C3 model is used in the descriptions, examples, demonstrations, and figures throughout the disclosure for illustrative purposes. In other aspects, various standards collapse strength models now known or later developed can be used in place of the API 5C3 model. The casing type of tubular structure is used in the descriptions, examples, demonstrations, and figures throughout the disclosure for illustrative purposes. In other aspects, various types of tubular structures now know or later developed can be used in place of the casing type of tubular structure. 
     This disclosure presents process and methods to improve the accuracy of calculations for collapse strength of high-collapse tubular structures, thereby reducing costs on tubular structure sections while continuing to meet or exceed borehole safety and integrity goals. Based on observations of tubular structure collapse strength versus tubular structure wall thickness, a determined percentage range can be utilized with a linear collapse strength model for a portion of the collapse strength calculation. Tubular structure collapse strength can be linearly related to the wall thickness of the tubular structure when the wall thickness is at or above a linear model limit, for example, 90.0%, 85.0%, 83.0%, or other values, of the initial wall thickness. Below the linear model limit, the standards collapse strength model can be used. 
     In some aspects, the disclosed processes and methods can utilize a hybrid approach to tubular structure design, in which the linear collapse strength model can be combined with the standards collapse strength model to produce a hybrid collapse strength model. In some aspects, a transition model can be utilized to bridge the linear collapse strength model and the standards collapse strength model to avoid a discontinuity of the hybrid collapse strength model at the point where the linear and standards models are proximate. The gap covered by the transition model can be various values, such as 0.1%, 0.5%, 2.0%, or other values. In some aspects, the hybrid collapse strength model can be applied to the calculation of a tubular structure wear allowance, such as for a casing section or a drill pipe. 
     Using the specified linear model limit, the collapse rating can be calculated using Equation 1. 
     Equation 1: Example Collapse Rating Calculation Using a Linear Model Limit Parameter 
     
       
         
           
             
               
                 P 
                 ⁢ 
                 c 
               
               = 
               
                 
                   t 
                   
                     t 
                     ⁢ 
                     0 
                   
                 
                 * 
                 Pc 
                 ⁢ 
                 
                     
                 
                 ⁢ 
                 0 
               
             
             , 
             
               
 
             
             ⁢ 
             
               
                 where 
                 ⁢ 
                 
                     
                 
                 ⁢ 
                 
                   
                     L 
                     ⁢ 
                     L 
                   
                   
                     1 
                     ⁢ 
                     0 
                     ⁢ 
                     0 
                   
                 
                 * 
                 t 
                 ⁢ 
                 0 
               
               ≤ 
               t 
               ≤ 
               
                 t 
                 ⁢ 
                 0 
               
             
           
         
       
     
     where Pc is the calculated collapse rating, 
     Pc0 is the collapse rating of the initial wall thickness of the tubular structure, 
     t0 is the initial wall thickness of the tubular structure, 
     t is the adjusted wall thickness of the tubular structure as wear and corrosion occur, and 
     LL is the linear model limit parameter in the range of 0.0 to 100.0, typically can be in the range of 70.0 and 99.0. The LL can be converted to a percentage in the calculations and applied to the initial wall thickness. 
     In some aspects, the tubular structure can exhibit characteristics where the collapse rating is not proportional to, while continuing to be linearly related to, the tubular structure wall thickness. In these aspects, Equation 2 can be utilized to calculate a new collapse rating, where the range covered by the linear collapse strength model utilizes a different collapse rating than the standards portion. 
     Equation 2: Example Non-Proportional Collapse Rating 
     
       
         
           
             
               
                 P 
                 ⁢ 
                 c 
               
               = 
               
                 
                   P 
                   ⁢ 
                   c 
                   ⁢ 
                   0 
                 
                 - 
                 
                   
                     ( 
                     
                       
                         P 
                         ⁢ 
                         c 
                         ⁢ 
                         0 
                       
                       - 
                       
                         P 
                         ⁢ 
                         c 
                         ⁢ 
                         1 
                       
                     
                     ) 
                   
                   ⁢ 
                   
                     
                       ( 
                       
                         1 
                         - 
                         
                           t 
                           
                             t 
                             ⁢ 
                             0 
                           
                         
                       
                       ) 
                     
                     
                       ( 
                       
                         1 
                         - 
                         
                           
                             L 
                             ⁢ 
                             L 
                           
                           
                             1 
                             ⁢ 
                             0 
                             ⁢ 
                             0 
                           
                         
                       
                       ) 
                     
                   
                 
               
             
             , 
             
               
 
             
             ⁢ 
             
               
                 where 
                 ⁢ 
                 
                     
                 
                 ⁢ 
                 
                   
                     L 
                     ⁢ 
                     L 
                   
                   
                     1 
                     ⁢ 
                     0 
                     ⁢ 
                     0 
                   
                 
                 * 
                 t 
                 ⁢ 
                 0 
               
               ≤ 
               t 
               ≤ 
               
                 t 
                 ⁢ 
                 0 
               
             
           
         
       
     
     where Pc1 is the linear model limit collapse rating. 
     In some aspects, a discontinuity can occur when combining the linear collapse strength model and the standards collapse strength model when generating the hybrid collapse strength model. To compensate for the discontinuity, a transition range can be included as part of the hybrid collapse strength model (see, for example,  FIG. 6 , transition line  640 ). The transition range can cover a range from the linear collapse strength model to the standards collapse strength model. The transition range can be specified parameter. For example, the hybrid collapse strength model can utilize a linear model limit of 90.0 and a transition range of 3.0, which means that the collapse rating would be calculated using the linear collapse strength model for a tubular structure wall thickness from the initial thickness to 90.0% of the initial wall thickness. The transition collapse strength model would be used for the wall thicknesses less than 90.0% to 87.0% of the initial wall thickness. The standards collapse strength model would be used for the wall thickness less than 87.0% of the initial wall thickness. Equation 3 is an example of calculating the transition collapse rating. 
     Equation 3: Example Transition Collapse Rating 
     
       
         
           
             
               Transitional 
               ⁢ 
               
                   
               
               ⁢ 
               Pc 
             
             = 
             
               
                 Pc 
                 ⁢ 
                 
                     
                 
                 ⁢ 
                 1 
               
               - 
               
                 
                   ( 
                   
                     
                       
                         L 
                         ⁢ 
                         L 
                       
                       
                         1 
                         ⁢ 
                         0 
                         ⁢ 
                         0 
                       
                     
                     - 
                     
                       t 
                       
                         t 
                         ⁢ 
                         0 
                       
                     
                   
                   ) 
                 
                 * 
                 
                   
                     ( 
                     
                       
                         P 
                         ⁢ 
                         c 
                         ⁢ 
                         1 
                       
                       - 
                       
                         P 
                         ⁢ 
                         
                           c 
                           api 
                         
                       
                     
                     ) 
                   
                   transitionRange 
                 
               
             
           
         
       
     
     where Pc api  is the standards collapse rating at the linear model limit, and 
     transitionRange is the decimal value of the range used for the transition collapse strength model. 
     Turning now to the figures,  FIG. 1  is an illustration of a diagram of an example drilling system  100 , for example, a logging while drilling (LWD) system, a measuring while drilling (MWD) system, a seismic while drilling (SWD) system, a telemetry while drilling (TWD) system, injection well system, extraction well system, and other borehole systems. Drilling system  100  includes a derrick  105 , a well site controller  107 , and a computing system  108 . Well site controller  107  includes a processor and a memory and is configured to direct operation of drilling system  100 . Derrick  105  is located at a surface  106 . 
     Extending below derrick  105  is a borehole  110  with downhole tools  120  at the end of a drill string  115 . Downhole tools  120  can include various downhole tools, such as a formation tester or a bottom hole assembly (BHA). At the bottom of downhole tools  120  is a drilling bit  122 . Other components of downhole tools  120  can be present, such as a local power supply (e.g., generators, batteries, or capacitors), telemetry systems, sensors, transceivers, and control systems. Borehole  110  is surrounded by subterranean formation  150 . 
     Well site controller  107  or computing system  108  which can be communicatively coupled to well site controller  107 , can be utilized to communicate with downhole tools  120 , such as sending and receiving telemetry, data, instructions, subterranean formation measurements, and other information. Computing system  108  can be proximate well site controller  107  or be a distance away, such as in a cloud environment, a data center, a lab, or a corporate office. Computing system  108  can be a laptop, smartphone, PDA, server, desktop computer, cloud computing system, other computing systems, or a combination thereof, that are operable to perform the processes described herein. Well site operators, engineers, and other personnel can send and receive data, instructions, measurements, and other information by various conventional means, now known or later developed, with computing system  108  or well site controller  107 . Well site controller  107  or computing system  108  can communicate with downhole tools  120  using conventional means, now known or later developed, to direct operations of downhole tools  120 . 
     Casing  130  can act as barrier between subterranean formation  150  and the fluids and material internal to borehole  110 , as well as drill string  115 . As drill string  115  rotates within borehole  110  or during trip in or trip out operations, there can be wear of casing  130 . Casing  130  should be designed to account for this wear for the operational lifetime of borehole  110 . Replacing casing sections of casing  130  can be scheduled though it can be more cost effective to design casing  130  prior to placement to avoid replacement during the operational lifetime of borehole  110 . 
       FIG. 2  is an illustration of a diagram of an example wireline system  200 . Wireline system  200  depicts a wireline well system and includes a derrick  205 , a well site controller  207 , and a computing system  208 . Well site controller  207  includes a processor and a memory and is operable to direct operation of wireline system  200 . Derrick  205  is located at a surface  206 . Computing system  208  can be proximate well site controller  207  or be a distance away, such as in a cloud environment, a data center, a lab, or a corporate office. Computing system  208  can be a laptop, smartphone, PDA, server, desktop computer, cloud computing system, and other computing systems. 
     Extending below derrick  205  is a borehole  210 , with a cased section  215   a , a cased section  215   b , and one uncased section  216 . Wireline  220  is inserted in borehole  210  to hold a downhole tool  225 . Borehole  210  is surrounded by a subterranean formation  235  which includes a hydrocarbon reservoir. Cased section  215   a  and cased section  215   b  can be designed to withstand subterranean formation  235  as well as the operations of downhole tool  225 . The design parameters of cased section  215   a  can vary from the design parameters of cased section  215   b . It is beneficial for cased section  215   a  and cased section  215   b  to be designed for the operational lifetime of borehole  210  to minimize the cost of replacing a section of casing. 
       FIG. 3  is an illustration of a diagram of an example offshore system  300  with an electric submersible pump (ESP) assembly  320 . ESP assembly  320  is placed downhole in a borehole  310  below a body of water  340 , such as an ocean or sea. Borehole  310 , protected by casing, screens, or other structures, is surrounded by subterranean formation  345 . ESP assembly  320  can be used for onshore operations. ESP assembly  320  includes a well controller  307  (for example, to act as a speed and communications controller of ESP assembly  320 ), an ESP motor  314 , and an ESP pump  324 . 
     Well controller  307  is placed in a cabinet  306  inside a control room  304  on an offshore platform  305 , such as an oil rig, above water surface  344 . Well controller  307  is configured to adjust the operations of ESP motor  314  to improve well productivity. In the illustrated aspect, ESP motor  314  is a two-pole, three-phase squirrel cage induction motor that operates to turn ESP pump  324 . ESP motor  314  is located near the bottom of ESP assembly  320 , just above downhole sensors within borehole  310 . A power/communication cable  330  extends from well controller  307  to ESP motor  314 . A fluid pipe  332  fluidly couples equipment located on offshore platform  305  and ESP pump  324 . 
     In some aspects, ESP pump  324  can be a horizontal surface pump, a progressive cavity pump, a subsurface compressor system, or an electric submersible progressive cavity pump. A motor seal section and intake section may extend between ESP motor  314  and ESP pump  324 . A riser  315  separates ESP assembly  320  from water  340  until sub-surface  342  is encountered, and a casing  316  can separate borehole  310  from subterranean formation  345  at and below sub-surface  342 . Perforations in casing  316  can allow the fluid of interest from subterranean formation  345  to enter borehole  310 . The design of casing  316  should be sufficient to prevent borehole  310  from collapsing for the lifetime of operations of borehole  310 . 
       FIG. 4  is an illustration of a diagram of an example hydraulic fracturing (HF) well system  400 , which can be a well site where HF operations are occurring through the implementation of a HF treatment stage plan. HF well system  400  demonstrates a nearly horizontal wellbore undergoing a fracturing operation. 
     HF well system  400  includes surface well equipment  405  located at a surface  404 , a well site controller  407 , a surface HF pump system  406 , and a computing system  408 . In some aspects, well site controller  407  is communicatively connected to separate computing system  408 , for example, a separate server, data center, cloud service, tablet, laptop, smartphone, or other types of computing systems capable of executing the processes and methods described herein. Computing system  408  can be located proximate to well site controller  407  or located a distance from well site controller  407 . 
     Extending below surface  404  from surface well equipment  405  is a borehole  410 . Borehole  410  can have zero or more cased sections, such as cased section  450  and cased section  452 , and a bottom section that is uncased. Inserted into borehole  410  is a fluid pipe  420 . The bottom portion of fluid pipe  420  has the capability of releasing downhole material  430 , such as carrier fluid with diverter material, from fluid pipe  420  to subterranean formations  435  containing fractures  440 . The release of downhole material  430  can be by perforations in the casing, by valves placed along fluid pipe  420 , or by other release means. At the end of fluid pipe  420  is an end of pipe assembly  425 , which can be one or more downhole tools or an end cap assembly. 
     As described in  FIGS. 1-3 , cased section  450  and cased section  452  can be designed to withstand subterranean formation  435  and operations internal of borehole  410  so as to reduce the chance that the respective cased sections would need to be replaced during the operational lifetime of borehole  410 . The design of cased section  450  and cased section  452  can be optimized to minimize cost while satisfying the operational goal. 
       FIGS. 1, 2, and 4  depict onshore operations. Those skilled in the art will understand that the disclosure is equally well suited for use in offshore operations, such as shown in  FIG. 3 .  FIGS. 1-4  depict specific borehole configurations, those skilled in the art will understand that the disclosure is equally well suited for use in boreholes having other orientations including vertical boreholes, horizontal boreholes, slanted boreholes, multilateral boreholes, and other borehole types. 
       FIG. 5  is an illustration of a diagram of an example graph  500  showing a gap between the API 5C3 collapse strength model and a controlled test. Graph  500  utilizes test data run through the API 5C3 collapse strength model and the same test data run through a controlled test. Graph  500  includes an x-axis  505  indicating the wall thickness of a selected tubular structure, in inches. A y-axis  506  indicates the collapse pressure in psi, e.g., the collapse rating. A key table  510  is shown indicating the data points collected using the API 5C3 collapse strength model as diamonds with a linear fit line that is a dashed line. The controlled test data is shown as circles with its linear fit line shown as a dotted line. 
     In plot area of graph  500 , the API 5C3 collapse strength model data points and linear fit line are plotted as API line  520 . The controlled test data points and linear fit line are plotted as test line  530 . Test line  530  demonstrates that the measured collapse strength can be linearly related to the tubular structure wall thickness. Therefore, a linear collapse strength model for a specified range of percentages of initial wall thicknesses can be a satisfactory estimate for tubular structure wear allowance. 
     The distance between API line  520  and test line  530  varies over the various wall thicknesses and is represented by gap  540 . Gap  540  represents the opportunity improvement of this disclosure, whereby a thinner wall thickness for tubular structures can be utilized to achieve the same or similar collapse pressure, e.g., collapse rating, as the API 5C3 collapse strength model. Thinner casing can be less expensive and use less space within the borehole, thereby increasing overall efficiency of the borehole operations. 
       FIG. 6  is an illustration of a diagram of an example graph  600  showing a hybrid collapse strength model. Graph  600  utilizes sample data run through a hybrid collapse strength model that includes the API 5C3 collapse strength model, as linear collapse strength model, and a transition collapse strength model. Graph  600  includes an x-axis  605  indicating the normalized wall thickness, in inches, of the tubular structure utilized. A y-axis  606  indicates the collapse pressure in psi, e.g., the collapse rating. A key table  610  is shown indicating the data points collected using the API 5C3 collapse strength model as squares with a linear fit line. The linear collapse strength model are shown as circles with a linear fit line. A transition collapse strength model is shown as a solid line. 
     In plot area of graph  600 , the API 5C3 collapse strength model data points and linear fit line are plotted as API line  620 . The linear collapse strength model data points and linear fit line are plotted as linear line  630 . The transition collapse strength model connecting API line  620  and linear line  630  is transition line  640 . Transition line  640  can be of a determined, default, or specified length, for example, 0.1%, 1.0%, 3.0%, or other values of the normalized wall thickness. In this example, transition line  640  is shown as being between approximately, 85.0% and 87.0% of the normalized wall thickness. The linear collapse strength model can be used for tubular structures at 100% of the normalized wall thickness down to the beginning of transition line  640 , such as 87.0%. Transition line  640  can extend to 85.0% of the initial wall thickness at which point the API 5C3 collapse strength model calculations are utilized to calculate the remaining wall thickness over the remaining life of the operations of the borehole. The handling of the transition points between the various collapse strength models is arbitrary and can utilize various combinations of greater than, less than, or equal to comparisons to define each transition point. 
       FIG. 7  is an illustration of a flow diagram of example method  700  using a hybrid collapse strength model. Method  700  can be performed on a computing system, such as a well site controller, a server, a laptop, a mobile device, a cloud computing system, or other computing system capable of receiving the input parameters and outputting result parameters. Other computing systems can be a smartphone, a mobile phone, a PDA, a laptop computer, a desktop computer, a server, a data center, a cloud environment, or other computing system. The computing system can be located proximate a borehole or can be located in a data center, a cloud environment, a lab, a corporate office, or other distance locations. Method  700  can be encapsulated in software code or in hardware, for example, an application, a code library, a dynamic link library, a module, a function, a RAM, a ROM, and other software and hardware implementations. The software can be stored in a file, database, or other computing system storage mechanism. Method  700  can be partially implemented in software and partially in hardware. 
     Method  700  starts at a step  705  and proceeds to a step  710  where input parameters are received. The input parameters can include, but is not limited to, the wall thickness of the selected tubular structure, the anticipated downhole conditions, for example, minerology factors, temperature factors, pressure factors, measured depth, true vertical depth, fluid exposure factors, electromagnetic exposure factors, and other downhole conditions, a selected tolerance factor, a designated standards collapse strength model to utilize, a linear model limit, and a transition range. In some aspects, default parameters can be utilized in place of receiving one or more of the input parameters, for example, the linear model limit can be defaulted to 90.0% or the transition range can be defaulted to 2.0%. In some aspects, a machine learning algorithm can be used in place of some of the input parameters, for example, the linear model limit and the transition range can be determined using an output from the machine learning algorithm to improve the efficiency of the method results. 
     Proceeding to a step  720 , a wear allowance parameter is updated utilizing the input parameters. The wear allowance parameter indicates the amount of wear allowable on the tubular structure before needing to be replaced. In a step  730 , the tubular structure wall thickness is updated using the output from step  720  and the input parameters. The process used in step  720  and step  730  can utilize conventional processes. 
     In a decision step  735 , the linear model limit can be compared to the updated tubular structure wall thickness as output by step  730 . The linear model limit can be various values, for example, 90.0% of the initial wall thickness, 80.0% of the initial wall thickness, or other values within the inclusive range of 0.0% and 100.0%. 0.0% would indicate that the linear collapse strength model is used for the calculations. 100.0% would indicate that the standards collapse strength model is used for the calculations. Typical values can be 60.0% to 95.0%, or other ranges. If the linear model limit is satisfied, e.g., that the wall thickness has been calculated to be reduced to the limit value, the ‘Yes’ option is selected. If the linear model limit is not satisfied, then the ‘No’ option is selected. 
     Proceeding from the ‘Yes’ option in decision step  735 , method  700  proceeds to step  740 . In step  740 , a designated collapse strength model, such as a standards collapse strength model, for example, the API 5C3 collapse strength model, is utilized to calculate the collapse rating for the given set of input parameters. In some aspects, a transition collapse strength model can be applied, e.g., be the designated collapse strength model, over a specified transition range prior to utilizing the standards collapse strength model. 
     Proceeding from the ‘No’ option in decision step  735 , method  700  proceeds to step  745 . In step  745 , the linear collapse strength model is utilized as the designated collapse strength model to calculate the collapse rating for the given set of input parameters. 
     From step  740  or step  745 , method  700  proceeds to a step  750  where the collapse safety factor is computed utilizing the respective output from step  740  or step  745 . In a decision step  755  the tolerance factor can be evaluated to determine if it is satisfied. For example, the difference between the collapse safety factor and a design safety factor can be compared to the tolerance factor, such as shown in Equation 4. If the tolerance factor is satisfied, the ‘Yes’ option is selected. If the tolerance factor is not satisfied, e.g., an unsatisfactory comparison, the ‘No’ option is selected. 
     Equation 4: Example Comparison of the Collapse Safety Factor and the Design Safety Factor 
       |SF−DF|&lt;tolerance factor
 
     where SF is the collapse safety factor, 
     DF is the design safety factor, and 
     Tolerance factor is the tolerance factor received in the input parameters or from a default parameter. 
     From the ‘No’ option of decision step  755 , method  700  proceeds to step  720  to enable further refinements of the wear allowance. From the ‘Yes’ option of decision step  755 , method  700  proceeds to step  760 . In step  760 , the wear allowance and other computed parameters can be output to one or more systems. Method  700  ends at a step  795 . 
       FIG. 8  is an illustration of a block diagram of an example hybrid collapse strength modeler system  800 , which can be implemented using one or more computing systems, for example, a well site controller, a reservoir controller, a data center, a cloud environment, a server, a laptop, a smartphone, a mobile phone, a tablet, and other computing systems. The computing system can be located proximate the well site, or a distance from the well site, such as in a data center, cloud environment, corporate location, a lab environment, or another location. The computing system can be a distributed system having a portion located proximate the borehole and a portion located remotely from the well site. In some aspects, hybrid collapse strength modeler system  800  can be implemented using tubular structure design controller  900  of  FIG. 9 . 
     Hybrid collapse strength modeler system  800 , or a portion thereof, can be implemented as an application, a code library, a dynamic link library, a function, a module, other software implementation, or combinations thereof. In some aspects, hybrid collapse strength modeler system  800  can be implemented in hardware, such as a ROM, a graphics processing unit, or other hardware implementation. In some aspects, hybrid collapse strength modeler system  800  can be implemented partially as a software application and partially as a hardware implementation. 
     Hybrid collapse strength modeler system  800  has a hybrid collapse strength modeler  810  that includes a parameter receiver  820 , a wear allowance modeler  830 , a linear collapse strength modeler  832 , a standards collapse strength modeler  834 , and a result transceiver  840 . The result parameters and outputs from hybrid collapse strength modeler  810  can be communicated to another system, such as one or more of a well site controller, a computing system, or a user. In some aspects, the communicated result parameters can be used as inputs to a design operation for the borehole to identify appropriate casing to be utilized. A memory or data storage of hybrid collapse strength modeler  810  can be configured to store the processes and algorithms for directing the operations thereof. 
     Parameter receiver  820  can receive input parameters to direct further operations. The input parameters can be parameters, instructions, directions, data, and other information to enable or direct the remaining processing of hybrid collapse strength modeler system  800 . For example, the input parameters can include the wall thickness of the selected tubular structure, the anticipated downhole conditions, for example, minerology factors, temperature factors, pressure factors, measured depth, true vertical depth, fluid exposure factors, electromagnetic exposure factors, and other downhole conditions, a selected tolerance factor, a designated standards collapse strength model to utilize, a linear model limit, and a transition range. 
     Wear allowance modeler  830  can implement the processes and methods as described herein utilizing the input parameters. Wear allowance modeler  830  can use one or more algorithms, such as machine learning, decision tree, random forest, logistic regression, linear, and other algorithms to determine the wear allowance parameter. Wear allowance modeler  830  can direct operation of the linear collapse strength modeler  832  and the standards collapse strength modeler  834 . 
     In some aspects, the transition collapse strength modeler can be implemented as a separate component or be combined in wear allowance modeler  830 , linear collapse strength modeler  832 , or standards collapse strength modeler  834 . In some aspects, the linear collapse strength modeler  832  and the standards collapse strength modeler  834  can be implemented in the same modeler. Hybrid collapse strength modeler system  800  demonstrates a functional view of the disclosure, and the described functions can be implemented in one or more functional units. 
     Result transceiver  840  can communicate one or more generated outputs and result parameters, such as a wear allowance parameter, to one or more other systems, such as a well site controller, a computing system, a user, or other borehole related systems. Parameter receiver  820  and result transceiver  840  can be, or can include, conventional interfaces configured for transmitting and receiving data. 
       FIG. 9  is an illustration of a block diagram of an example of a tubular structure design controller  900  according to the principles of the disclosure. Tubular structure design controller  900  can be stored on a single computer or on multiple computers. The various components of tubular structure design controller  900  can communicate via wireless or wired conventional connections. A portion of tubular structure design controller  900  can be located downhole at one or more locations and other portions of tubular structure design controller  900  can be located on a computing device or devices located at the surface or a distant location. In some aspects, tubular design controller  900  can be wholly located at a surface or distant location. In some aspects, tubular structure design controller  900  is part of a borehole planner system or a wellsite job planner system, and can be integrated in a single device. 
     Tubular structure design controller  900  can be configured to perform the various functions disclosed herein including receiving input parameters and generating result parameters from an execution of a stress analysis using a hybrid modeler, such as a thermal modeler and a strength modeler. Tubular structure design controller  900  includes a communications interface  910 , a memory  920 , and a processor  930 . 
     Communications interface  910  is configured to transmit and receive data. For example, communications interface  910  can receive input parameters regarding the tubular structure and the anticipated conditions that will be experienced downhole a borehole. Communications interface  910  can transmit the result parameters and other generated parameters, such as calculated safety factors over time at various borehole depths. In some aspects, communications interface  910  can transmit a status, such as a success or failure indicator of tubular structure design controller  900  regarding receiving the input parameters, transmitting the result parameters, or generating the result parameters. In some aspects, communications interface  910  can receive input parameters from a machine learning system, such as borehole conditions that could be experienced downhole during the time interval of the analysis. Communications interface  910  can communicate via communication systems used in the industry. For example, wireless or wired protocols can be used. Communication interface  910  is capable of performing the operations as described for parameter receiver  820  and result transceiver  840 . 
     Memory  920  can be configured to store a series of operating instructions that direct the operation of processor  930  when initiated, including the code representing the algorithms for determining the safety factors for a hybrid collapse strength model. Memory  920  is a non-transitory computer readable medium. Multiple types of memory can be used for data storage and memory  920  can be distributed. 
     Processor  930  can be configured to determine result parameters and statuses utilizing the received input parameters, and, if provided, the machine learning system inputs. For example, the processor  930  can perform a collapse rating analysis using a hybrid collapse strength model on the tubular structure by applying the anticipated downhole conditions. Processor  930  can be configured to direct the operation of the tubular structure design controller  900 . Processor  930  includes the logic to communicate with communications interface  910  and memory  920 , and perform the functions described herein to determine the result parameters and statuses. Processor  930  is capable of performing or directing the operations as described by wear allowance modeler  830 , linear collapse strength modeler  832 , and standards collapse strength modeler  834 . 
     A portion of the above-described apparatus, systems or methods may be embodied in or performed by various analog or digital data processors, wherein the processors are programmed or store executable programs of sequences of software instructions to perform one or more of the steps of the methods. A processor may be, for example, a programmable logic device such as a programmable array logic (PAL), a generic array logic (GAL), a field programmable gate arrays (FPGA), or another type of computer processing device (CPD). The software instructions of such programs may represent algorithms and be encoded in machine-executable form on non-transitory digital data storage media, e.g., magnetic or optical disks, random-access memory (RAM), magnetic hard disks, flash memories, and/or read-only memory (ROM), to enable various types of digital data processors or computers to perform one, multiple or all of the steps of one or more of the above-described methods, or functions, systems or apparatuses described herein. 
     Portions of disclosed examples or embodiments may relate to computer storage products with a non-transitory computer-readable medium that have program code thereon for performing various computer-implemented operations that embody a part of an apparatus, device or carry out the steps of a method set forth herein. Non-transitory used herein refers to all computer-readable media except for transitory, propagating signals. Examples of non-transitory computer-readable media include, but are not limited to: magnetic media such as hard disks, floppy disks, and magnetic tape; optical media such as CD-ROM disks; magneto-optical media such as floppy disks; and hardware devices that are specially configured to store and execute program code, such as ROM and RAM devices. Examples of program code include both machine code, such as produced by a compiler, and files containing higher level code that may be executed by the computer using an interpreter. 
     In interpreting the disclosure, all terms should be interpreted in the broadest possible manner consistent with the context. In particular, the terms “comprises” and “comprising” should be interpreted as referring to elements, components, or steps in a non-exclusive manner, indicating that the referenced elements, components, or steps may be present, or utilized, or combined with other elements, components, or steps that are not expressly referenced. 
     Those skilled in the art to which this application relates will appreciate that other and further additions, deletions, substitutions and modifications may be made to the described embodiments. It is also to be understood that the terminology used herein is for the purpose of describing particular embodiments only, and is not intended to be limiting, because the scope of the present disclosure will be limited only by the claims. Unless defined otherwise, all technical and scientific terms used herein have the same meaning as commonly understood by one of ordinary skill in the art to which this disclosure belongs. Although any methods and materials similar or equivalent to those described herein can also be used in the practice or testing of the present disclosure, a limited number of the exemplary methods and materials are described herein.