Abstract:
A process for reducing wellbore instability includes inputting pre-drilling assessment information into an hydraulics analysis and wellbore stability application, inputting a well plan into the hydraulics and wellbore analysis application, inputting a parameter measured at the wellsite into the hydraulics and wellbore stability analysis application, inputting an observation made at the wellsite into the hydraulics and wellbore stability analysis application, integrating the pre-drilling assessment information, the measured parameter, and the observation into the wellbore strengthening analysis application, and adjusting a drilling fluid parameter in response to the integrated pre-drilling assessment information, the measured parameter, and the observation.

Description:
BACKGROUND OF INVENTION 
       [0001]    Geomechanical and drilling fluid engineers share the common goal of maintaining proper mud weights to minimize wellbore instability during drilling. However, their efforts are often out of sync with regard to time frame, data resources, uncertainties, responsibilities, and sense of urgency. Attempts to resolve these issues in the past have encountered mixed results, primarily because the two groups utilize different technology and communicate differently. 
         [0002]    Wellbore stability planning on complex wells is the domain of geomechanical engineers who base their recommendations on offset log analyses, well histories, geomechanical models, and knowledge of the area. Using these recommendations as guidelines, rig personnel respond to changing and unexpected well conditions by continually monitoring and adjusting mud properties and drilling practices. However, drilling fluid engineers charged with recommending and maintaining proper mud weights rarely have access, training, or time to execute geomechanical software as part of their duties. Likewise, geomechanical engineers rarely get continual updates (unless problems are encountered) and their software usually is not designed to handle certain types of data, including fuzzy data provided by wellsite drilling personnel. 
         [0003]    Wellbore instability is one underlying cause of non-productive time during well construction. While a diversity of parameters affect the instance and degree of instability, factors including downhole mud density and equivalent circulating density profiles can contribute to wellbore instability when these densities are not appropriate for a particular formation or well profile, especially in highly deviated wells. Optimum mud weights are selected based on offset well analyses, detailed well plans, analyses and interpretation of ongoing well conditions, considerations for different density-dependent operations, and recommendations from other wellsite personnel including drilling fluids engineers, also called mud engineers. This multi-pronged approach, may result in uncertainty, lose effectiveness when information and resources are not readily available or the information is not communicated with everyone involved in making decisions and implementing solutions. Efforts can be out of sync with regard to time frame in which solutions should be implemented, data resources used to make decisions, uncertainties, responsibilities, and sense of urgency in a given situation. 
       SUMMARY 
       [0004]    In one aspect, the claimed subject matter is generally directed to a method for reducing wellbore instability. A process for reducing wellbore instability includes inputting pre-drilling assessment information into an hydraulics analysis and wellbore stability application, inputting a well plan into the hydraulics and wellbore analysis application, inputting a parameter measured at the wellsite into the hydraulics and wellbore stability analysis application, inputting an observation made at the wellsite into the hydraulics and wellbore stability analysis application, integrating the pre-drilling assessment information, the measured parameter, and the observation into the wellbore strengthening analysis application, and adjusting a drilling fluid parameter in response to the integrated pre-drilling assessment information, the measured parameter, and the observation. 
         [0005]    In another aspect of the claimed subject matter, an application for integrating geomechanics and drilling fluids engineering includes a wellbore stability engine, an input processor providing wellsite data to the wellbore stability engine, the input processor also providing a pre-drilling plan to the wellbore stability engine, the third party data being provided to the wellbore stability engine, and a report generated by the wellbore stability engine, the report including information resulting from third party data, the pre-drilling plan, and data measured at the wellsite. 
         [0006]    In yet another aspect, the claimed subject matter relates to a method for generating wellbore stability reports including inputting an initial parameter into a wellbore stability engine, providing a well plan from the wellbore stability engine based on the initial parameter, inputting a wellsite parameter into an input processor, inputting the well plan into the input processor, providing the wellsite parameter and well plan from the input processor to the wellbore stability engine, and generating a report from the wellbore stability engine based on the wellsite parameter and well plan from the input processor. 
         [0007]    Other aspects and advantages of the claimed subject matter will be apparent from the following description and the appended claims. 
     
    
     
       DESCRIPTION OF THE DRAWINGS 
         [0008]      FIG. 1  is a schematic of a wellbore illustrating different types of instabilities. 
           [0009]      FIG. 2  is a process flow diagram in accordance with embodiments disclosed herein. 
           [0010]      FIG. 3  is a graphical report generated in accordance with embodiments disclosed herein. 
           [0011]      FIG. 4  is a screenshot of a three dimensional visualization of a geomechanical analysis in accordance with embodiments disclosed herein. 
       
    
    
     DETAILED DESCRIPTION 
       [0012]    To define more clearly the terms used herein, the following definitions are provided. To the extent that any definition or usage provided by any document incorporated herein by reference conflicts with the definition or usage provided herein, the definition or usage provided herein controls. 
         [0013]    The term “wellbore stability” is used herein to mean 
         [0014]    The term “equivalent circulating density” is used herein to mean the effective density exerted by a circulating fluid against the formation that takes into account the pressure loss in the annulus above the depth being considered. 
         [0015]    The term “equivalent static density” is used herein to mean the effective density a depth of interest of a static column of fluid exposed to downhole temperatures and pressures. 
         [0016]    The term “high temperature/high pressure” is used herein to mean a well having an undisturbed bottomhole temperature of greater than 300° F. [149° C.] and a pore pressure of at least 0.8 psi/ft (˜15.3 lbm/gal). 
         [0017]    The term “breakout” is used herein to mean the occurrence where near-wellbore rocks break into pieces and fall in the well. 
         [0018]    The term “caving” is used herein to mean the occurrence of pieces of rock that came from the wellbore but that were not removed directly by the action of the drill bit. Cavings can be splinters, shards, chunks and various shapes of rock, usually spalling from shale sections that have become unstable. The shape of the caving can indicate why the rock failure occurred. 
         [0019]    The term “pre-drill assessment” is used herein to mean wellbore stability evaluation and assessment before drilling. 
         [0020]    The term “well plan” is used herein to mean the description of a proposed wellbore, including the shape, orientation, depth, completion, and evaluation. 
         [0021]    The term “rock-failure model” is used herein to mean a model to evaluate how the rock fails either in compressive failure or in tensile failure. 
         [0022]    The term “linear elastic model” is used herein to mean the relationship between the force and the deformation is linear and there is no residual deformation when the force is removed. 
         [0023]    The term “modified Lade failure criterion” is used herein to mean a failure criterion which considers more general stress state than other failure criteria. 
         [0024]    The term “lost circulation” is used herein to mean mud loss to the formation. 
         [0025]    The term “tight hole” is used herein to mean a section of a wellbore, usually openhole, where larger diameter components of the drillstring, such as drillpipe tool joints, drill collars, stabilizers, and the bit, may experience resistance when the driller attempts to pull them through these sections. 
         [0026]    The term “washout” is used herein to mean an enlarged region of a wellbore. 
         [0027]    The claimed subject matter relates to a process for minimizing wellbore instability issues and an application for integrating geomechanical analyses conducted prior to drilling a wellbore, updating said analyses and recommending remedial actions using observations and data collected during drilling and tripping operations. A process that integrates efforts by geomechanical and mud engineers who share the common goal of recommending mud weights to solve wellbore instability issues is discussed herein. 
         [0028]    Referring to  FIG. 1 , a schematic of a wellbore  10  is shown with different types of instabilities. When a well is drilled, the rock surrounding the hole takes the load that was previously supported by the removed rock. As a result, an increase in stress around the wall of the borehole  18 , a stress concentration, is produced. Examples of events that can occur when the mud weight is too high include fractures and/or mud loss  12 . Mud loss or lost circulation can occur when equivalent static densities and equivalent circulating densities exceed the formation fracture resistance. If the rock is not strong enough or if the mud weight is not high enough to support the wellbore, the borehole may fail in shear in the form of tight hole  14 , sloughing (rock fragments break off from the wall and fall in the wellbore), or caving and hole collapse  16  or hole enlargement. Tight hole  14 , breakouts, cavings  16 , and/or destructive hole collapse can result when equivalent static densities are too low. When pressure margins between fracture and hole collapse are very low, such as those encountered in deepwater and high temperature/high pressure drilling, the potential for wellbore instability issues, such as those described, increases. 
         [0029]    On a rig, drilling fluid engineers work to maintain drilling fluid properties such as density, rheological properties, and chemical properties. Geomechanical engineers generate boundaries for operating mud windows and recommended mud-weight strategies, based on analyses of offset log data, well histories, geomechanical models, and knowledge of the area based on formation characterization and pre-drill wellbore stability (WBS) studies. Most geomechanical engineers work in an office environment using complex computer models and/or laboratory testing techniques to address stability issues from mechanical and stress perspectives and to conduct in-depth root-cause analyses. Interactions between the drilling fluid engineers and the geomechanical engineers can occur either before spud when mud engineers need geomechanical assistance for supporting mud programs, or during well construction when geomechanical engineers are following an existing or potentially major wellbore instability problem. 
         [0030]    Many complex wells are highly dependent on detailed geomechanics studies, and perhaps could not be drilled without proper planning. However, no plan can anticipate well conditions to the extent that instability problems are effectively and consistently mitigated. Some parameters can only be estimated during planning. 
         [0031]    Drilling fluid engineers focus on a wide range of drilling fluid issues at the wellsite, especially mud weight for well integrity and wellbore stability. Pre-drill plans may be continually adjusted to address changing drilling conditions and well events observed real-time at the wellsite. Unfortunately, most drilling fluid engineers are unable to integrate complex geomechanical analyses into their normal duties. 
         [0032]    Clearly, A process has been developed to integrate geomechanical and drilling fluid engineering wellbore stability processes. The process is controlled by an application to be used at the wellsite by drilling fluid engineers because of their proximity to drilling operations and their responsibilities as first responders in the event of a wellbore instability issue. The process and application seamlessly (a) convert field observations and measurements into data used by a rigorous stability model and other wellbore stability and strengthening applications, and (b) generate wellbore stability reports and interactive three dimensional (3D) visualization models of the downhole wellbore environment. The approach minimizes additional effort in the field by the drilling fluid engineer to generate useful wellbore stability analyses and information. 
         [0033]    Integrated Workflow 
         [0034]    The flowchart in  FIG. 2  presents an integrated process ( 100 ). The deliverers  101  include a geomechanical engineer  102  and a drilling fluid engineer  132 . The upper pateh  110  shows the process followed by the geomechanical engineer  102 . At the right side of the geomechanical process  110 , the deliverable to the operator  114  is the well plan  120 . To create the well plan  120 , the geomechanical engineer  102  takes many factors into account. These factors may include client and third party data  104 , including data from the wellsite and/or nearby wells, offset well data  106 , and planning simulations  108 , including geomechanical models. 
         [0035]    The lower path  130  represents the process for drilling fluid engineers. The drilling fluid engineer process incorporates the well plan  120  and wellsite measurements and observations  152 , calculations and wellsite simulations  154  to address stability issues. The deliverable for the drilling fluid engineer process  130  is a wellbore stability report  156  for delivery to wellsite and operator staff personnel  116  and  114 . Such wellbore stability reports  156  may be prepared daily. 
         [0036]    Continuing to refer to  FIG. 2 , the “WBS Engine”  140  is used by both the drilling fluid engineer process  130  and the goemechanical engineer process  110 . The quantity of complex input parameters used by geomechanical software models has previously been barrier for its use by drilling fluids engineers who may not be well versed in geomechanics theories and principles. Mud engineers have little access, training, or time to execute sophisticated geomechanical models and software as part of their normal duties. 
         [0037]    The “input processor”  150  accepts traditional observations  152  and measurements  154  collected by drilling fluid engineers  132  as inputs as well as those collected by the rig. Such inputs include, for example, drilling fluid density, drilling fluid composition and/or type, flow rates, penetration rate, rotary speed, weight on bit, and fluid temperature. The input processor  150  automatically uses observations  152 , measurements  154 , and data from the well plan  120  through fuzzy logic methods to generate the input values used to drive the WBS engine  140  regardless of its complexity. Results are generated and may be provided in the form of a wellbore stability report  156 . The reports can be provided to rig supervisory personnel  116 , the operator  114 , and/or the geomechanical engineers  102  responsible for the drilling and geomechanical well plans  120 . 
         [0038]    The integrated geomechanical process  100  allows the geomechanical engineer  102  to develop a well plan  120  utilizing operating windows based on the best available pre-drill assessment of earth stresses. The same application then allows drilling fluid engineers  132  to use the well plan  120  as a starting point, and combine it with current data, observations and measurements  152  and simulations  154  to uniquely adjust the operating window or other actions at the wellsite as drilling progresses. 
         [0039]    For the process  100  to succeed, the well plan  120  generated by the geomechanical engineer  102  is integrated into the WBS engine  140 . This permits access from the wellsite module, which directs the drilling fluid engineer process  130  and minimizes duplication of data entry and complex processing such as equivalent static densities and equivalent circulating densities. The geomechanical engineer  102 , generates the well plan  120  but may not have access to operator and quality offset well information  104 ,  106  which could be included. Assistance from resident experts and information from third-party data  104  and geomechanical studies  108  may be included as factors in developing the well plan  120  for complex wells, such as wells that are difficult to drill or costly to drill, including deep, deepwater, high temperature/high pressure, wells requiring extended reach drilling and ultra extended reach drilling, and wells drilled in remote locations. 
         [0040]    WBS Engine 
         [0041]    The platform for the integrated geomechanics process is the WBS engine  140 . The WBS engine  140  may be, for example a wellbore hydraulics analyses software package for simulations involving downhole equivalent static densities, equivalent circulating densities, pump pressures, temperature profiles, hole-cleaning, surge-swab, and other drilling engineering operations and issues. 
         [0042]    Techniques and strategies used in the WBS engine  140  may also be used to conduct detailed geomechanical analyses. The WBS engine  140  may use a finite-difference scheme to sub-divide wells into short segments, each with its own set of properties. The subdivision of wells into short segments allows integration of parameters specific to wellbore stability analyses, including earth stresses, rock properties, and pore pressures. The effects of temperature and pressure on downhole drilling fluid density and rheology and simulated equivalent circulating density profiles maybe combined with rock-failure models to determine the state of wellbore integrity based on current operating conditions. A consideration in making this determination is the ability to translate contextual and fuzzy inputs into parameters which are used for the geomechanical model using the input processor  150  described previously. 
         [0043]    One application of the wellbore hydraulics analyses software is to simulate the equivalent density profile based on current operating conditions and time-dependent downhole fluid properties. Positioning the equivalent static density and equivalent circulating density profiles within defined operating windows based on pore pressures and fracture gradients during any well-construction operation can be used to ensure wellbore integrity or stability. This task is performed as part of both office-based project, or geomechanical process  110  and wellsite engineering process, or drilling fluid engineer process  130 , during planning and operational stages, respectively. 
         [0044]    Deviations from the well plan  120  or unexpected occurrences can be quickly and easily incorporated into the wellbore stability and strengthening analyses to help achieve wellbore integrity. Referring to  FIG. 3 , an example of how unplanned events are superimposed over graphical snapshots to visually demonstrate integration of geomechanical results and hydraulics analyses to present a comprehensive view of wellbore stability is shown.  FIG. 3  shows a graphical report  200  such as that which may be generated by the WBS engine  140 . The report  200  shows the depth of drilling  202 , the well geometry  204 , inclination  206 , WBS density,  208 , downhole stresses  210 , pressure profile  212 , and comments  214 . The inclination  206  is graphed along the depth of the well as a percentage and shown at line  216 . The WBS Density  208  shows the mud weight  218 , the equivalent circulating density  220 , and the maximum stable mud weight  222  along the depth of the well. The graph of downhole stresses  210  shows the minimum horizontal stress  224  and the overburden gradient  226  along the depth of the well. The pressure profile graph  212  shows the pore pressure  228 , the equivalent circulating density  230  and the fracture gradient  232  along the depth of the well. A first unplanned event  234  is shown on the pressure profile  212 . The first unplanned event was a tight hole. A second unplanned event  236  is also shown on the pressure profile  212 . The second unplanned event was lost circulation. The unplanned events can be found in the comments column  214 . Conventional companion summary reports may also be generated and submitted to rig supervisors. 
         [0045]    Referring to  FIG. 4 , calculated downhole stress fields may also be added to an interactive 3D visualization  300  which may be used to examine the inside of virtual wellbores  302  while navigating the well from surface to the total depth, that is to the planned end of the well as measured by the length of pipe required to reach the bottom. A standard PC and a gamepad, joystick, and/or keyboard may be used to navigate a virtual wellbore  302 . Three dimensional perspectives may show radial stress distributions  304  and the position and extent of wellbore instability issues around the wellbore at depths of interest. An example of a wellbore instability issue is shown in  FIG. 4  as a breakout  306 . The stress distributions  304  and any wellbore instability issues are superimposed over internal and side projections of well tortuosity, cuttings beds, the drill string (including eccentricity), annular velocity profiles, downhole engineering parameters (temperatures, equivalent static densities, etc.), and downhole tools. The 3D visualization permits drilling fluid engineers and other personnel who may not be familiar with geomechanical intricacies to easily appreciate and visualize the scope and nature of wellbore instabilities and to quickly evaluate the impact and effectiveness of any adjustments. 
         [0046]    The mud weight window serves as one design factor for the design of both the well and drilling fluid system. It defines the range between the minimum weight to avoid well collapse (compressive or shear failure) and the maximum mud weight to avoid formation breakdown (tensile failure). Compressive or shear failure depends on the borehole stress and rock strength or failure criterion, while tensile failure or fracturing depends on the borehole stress and formation fracture gradient. 
         [0047]    As previously discussed, when a well is drilled, the rock surrounding the hole takes the load that was previously supported by the removed rock resulting in an increase in stress around the wall of the borehole. If the rock is not strong enough or if the mud weight is not high enough to support the wellbore, the borehole may fail in shear in the form of tight hole, sloughing (rock fragments break off from the wall and fall in the wellbore), or caving and hole enlargement. 
         [0048]    When the borehole pressure is too high, that is, when the borehole pressure is higher than the fracture pressure, then fracturing or splitting of the borehole occurs, resulting in mud loss and possible well-control issues. Fracture gradients may be projected based on fracturing measurements made on offset wells or at depths less that the depths of interest. Such fracturing measurements may come from leakoff tests and formation integrity tests. Formation fracture gradients may also depend on well deviation and trajectories that are different than those where the measurements were taken. Wellbore stability models extrapolate data to predict look-ahead scenarios based on these differences, and any available well testing or drilling event data. Various wellbore stability models may be used. The WBS engine  140  may use a linear elastic model that addresses deviated wellbores under anisotropic stresses. the linear elastic model addresses many of the drilling events observed at the wellsite, such as fracturing, loses of mud, tight holes, and cavings. 
         [0049]    The WBS engine  140  may also use the modified Lade failure criterion. The modified Lade criterion is a three-dimensional failure criterion that uses two empirical constants which may be determined from triaxial tests. 
         [0050]    Implementation 
         [0051]    A component of the process is the capturing and archiving of wellbore stability-related events and observations made by the drilling fluid engineer, and the subsequent use of the events and observations to calibrate wellbore stability model parameters for the analyses. This near-real-time update to the geomechanics model elevates the process beyond traditional approaches where geomechanics experts often do not participate in wellsite activities or interact with wellsite personnel during the drilling phase. The archived events and observations can be presented daily or on demand to wellsite personnel, and can also be used for end-of-well analyses and planning of subsequent wells drilled in the region. 
         [0052]    Examples of wellbore stability-related events captured in the WBS engine  140  include lost circulation, tight hole, washout, hole collapse, and wellbore influx. Data associated with the event can then be used to adjust geomechanical model parameters using fuzzy and contextual data. For example, a severe lost circulation zone may indicate deficiencies in accurate modeling of stress regimes, or it may indicate weaker-than-expected rock properties. This information further combined with bit parameters such as mechanical specific energy can be used to distinguish stress-regime and rock-property effects. Integration of the geomechanical analyses into the WBS engine  140  also allows interactive investigation of the impact of one parameter on another parameter. For example, flow rate increases that assist with hole cleaning may also increase equivalent circulating density profiles and cause stability concerns. Another example of the application of fuzzy and contextual data in the WBS engine  140  is how changes in mud density to maintain adequate equivalent static densities impact the equivalent circulating densities and flow rates that maintain wellbore stability and satisfy hole-cleaning requirements. These simulations can be performed at the wellsite by the drilling fluid engineer to ensure that optimum drilling conditions are maintained. 
         [0053]    This process uses available mud engineering and mud logging data to characterize wellbore response to different drilling operations and transformation of “fuzzy” observations into engineering values to drive the analytical model. This process further provides the use of real-time drilling data to provide real-time wellbore stability-related information. 
         [0054]    The current linear elastic model may be updated to consider poro-elasticity and thermal and chemical effects on stresses near the wellbore. While complex models use a variety of additional rock properties and empirical constants for input, much of the supporting information already is simulated. Other data can be incorporated through the input processor  150 . 
         [0055]    Additional models and inputs may be developed and calibrated into additional geomechanics modules or utilities. For example a fracture-width prediction module may be added to provide information relevant to the selection of lost-circulation-material blends and concentrations for wellbore strengthening applications. 
         [0056]    Geomechanical and wellsite drilling fluid engineers share the common goal of recommending mud weights to effectively mitigate, diagnose, and remediate wellbore stability issues. 
         [0057]    The process provides information to first-responder drilling fluid engineers, with full consideration of their lack of time, resources, and training to apply complex methods for analyzing geomechanical conditions at the wellsite. 
         [0058]    Integration of wellbore-stability software tools into an hydraulics program provides the ability to execute rigorous stability analyses enhanced by observations and measurements made at the wellsite. 
         [0059]    Additional benefits include incorporating wellbore stability analyses into an interactive system that models and visualizes changing downhole conditions. 
         [0060]    Field observations and real-time drilling measurements can be converted into parameters used by wellbore stability models in the WBS engine  140 . 
         [0061]    While the claimed subject matter has been described with respect to a limited number of embodiments, those skilled in the art, having benefit of this disclosure, will appreciate that other embodiments can be devised which do not depart from the scope of the claimed subject matter as disclosed herein. Accordingly, the scope of the claimed subject matter should be limited only by the attached claims.