Automated workflows using transient, multiphase analysis to improve well control planning for managed pressure drilling operations

Abstract

An Influx Management Envelopes (IME) for MPD through a cloud-based solution is generated, simplifying the process for routine application in drilling operations and providing parallel computing to enhance the efficiency of IME generation by parameterizing various influx scenarios. Utilizing a transient multiphase flow engine, the study establishes kick tolerance thresholds for safe influx volume determination. The analysis includes assessing associated risks during kick circulation using MPD system. Parallel computing facilitates faster computations and improved scalability. The combined approach integrates simulation results into an operational envelope for safer decision-making. The IME may be determined considering company well control policies, for adherence to established guidelines and maintain a consistent and standardized approach to well control practices. Collaborative workflows facilitate seamless teamwork, communication, and coordination. The integration of a collaborative framework enables effective sharing of expertise and contributes significantly to a comprehensive understanding of drilling operations.

What is claimed is: 
     
         1 . A method of determining an influx management envelope for a wellbore extending through an earth formation, the method including:
 using dynamic pressure model of a simulation cluster, for a drilling fluid density and each of a plurality of choke pressures, generating an output including a dynamic pressure profile of an annular pressure of the drilling fluid throughout the wellbore; and   for each output, using a multiphase transient model of the simulation cluster, determining a post influx surface pressure for each of a plurality of influx volumes.   
     
     
         2 . The method of  claim 1 , further comprising generating additional outputs including additional dynamic pressure profiles of the annular pressure for each of a plurality of drilling fluid densities and each of the plurality of choke pressures using the dynamic pressure model. 
     
     
         3 . The method of  claim 1 , further comprising, for each output, based on a pore pressure of the earth formation and the output of the dynamic pressure model, determining regions of the earth formation where the pore pressure is greater than the annular pressure of the drilling fluid for a respective given choke pressure and drilling fluid density. 
     
     
         4 . The method of  claim 1 , further comprising determining, using the multiphase transient model, whether the post influx surface pressure exceeds a threshold pressure of managed pressure drilling equipment. 
     
     
         5 . The method of  claim 1 , further comprising determining, using the multiphase transient model, whether the post influx surface pressure is within operating conditions for a threshold pressure of managed pressure drilling equipment. 
     
     
         6 . The method of  claim 1 , further comprising determining a maximum surface pressure that may be applied to the drilling fluid to maintain the annular pressure of the drilling fluid between a pore pressure of the earth formation and a maximum tolerated annular pressure of the drilling fluid throughout the wellbore for a plurality of influx volumes. 
     
     
         7 . The method of  claim 6 , wherein determining a maximum surface pressure that may be applied to the drilling fluid to maintain the annular pressure of the drilling fluid between a pore pressure of the earth formation and a maximum tolerated annular pressure of the drilling fluid includes determining a maximum surface pressure that may be applied to the drilling fluid to maintain the annular pressure of the drilling fluid between the pore pressure and a fracture pressure of the earth formation. 
     
     
         8 . The method of  claim 1 , wherein generating an output including a dynamic pressure profile of an annular pressure includes generating each of:
 an equivalent circulating density profile of a drilling fluid within the wellbore;   an equivalent static density profile of the drilling fluid within the wellbore; and   a temperature profile along the wellbore.   
     
     
         9 . The method of  claim 8 , further comprising wherein determining a maximum choke pressure that may be applied to the drilling fluid includes determining the maximum choke pressure that may be applied to the drilling fluid based on the at least one of the equivalent circulating density profile, the equivalent static density profile, or the temperature profile along the wellbore. 
     
     
         10 . The method of  claim 1 , wherein determining a surface pressure includes determining a surface pressure to maintain a bottomhole pressure constant while the influx volume is circulated to the surface. 
     
     
         11 . The method of  claim 1 , wherein determining a post influx surface pressure of a plurality of influx volumes includes determining whether the post influx surface pressure of the plurality of influx volumes is greater than a threshold surface pressure. 
     
     
         12 . The method of  claim 1 , wherein determining a post influx surface pressure for each of a plurality of influx volumes includes determining the post influx surface pressure for each of the plurality of influx volumes at each of a plurality of casing shoe pressures. 
     
     
         13 . The method of  claim 1 , further comprising based on the output, determining a minimum density of the drilling fluid to prevent a blowout. 
     
     
         14 . The method of  claim 1 , wherein generating an output including a dynamic pressure profile of an annular pressure of the drilling fluid throughout the wellbore includes generating the output for a plurality of drilling fluid densities. 
     
     
         15 . The method of  claim 1 , further comprising determining, for each output, regions of the earth formation. 
     
     
         16 . A method of generating an influx management envelope for a wellbore, the method comprising:
 for a first influx volume, determining transient temperatures and pressures along the wellbore and a composition of the first influx volume for each of a plurality of sets of wellbore parameters using an equation of state transient multiphase model in a simulation cluster;   determining a post influx surface pressure as a result of the first influx volume for each of the plurality of sets of wellbore parameters; and   for a second influx volume and each of the plurality of sets of wellbore parameters, determining in parallel using the equation of state transient multiphase model in the simulation cluster, a post influx surface pressure as a result of the second influx volume at each of the plurality of sets of wellbore parameters.   
     
     
         17 . A method of generating an influx management envelope for a wellbore, the method comprising:
 using a dynamic pressure model, generating a dynamic pressure profile of a wellbore for a drilling fluid having a density;   receiving an output from the dynamic pressure model with a transient multiphase model and determining a post influx surface pressure of the drilling fluid for a given influx volume;   determining whether the post influx surface pressure exceeds a pressure threshold; and   determining whether to change circulation of the drilling fluid, whether to change managed pressure drilling equipment, or whether to utilize secondary well control equipment to mitigate the influx volume.   
     
     
         18 . The method of  claim 17 , further comprising changing the circulation of the drilling fluid, changing the managed pressure drilling equipment, or utilizing secondary well control equipment. 
     
     
         19 . The method of  claim 17 , wherein the transient multiphase model accounts for transient phase changes of the influx (kick) between a liquid phase, a liquid-gas phase, and a gas phase based on the pressure profile. 
     
     
         20 . The method of  claim 17 , wherein the post influx surface pressure of the drilling fluid is determined for a plurality of different influx volumes for the drilling fluid substantially simultaneously.