Automated offset selection method for dowhnole tool performance evaluation

Abstract

A method for selecting potential offset drilling runs to automatically evaluate a drilling performance of a subject drilling run includes identifying the potential offset drilling runs based upon the subject drilling run. The potential offset drilling runs are identified based upon a status of a drilling system component that is used to drill the subject drilling run. The method also includes determining a score for each of the potential offset drilling runs, ranking the potential offset drilling runs based upon the score of each of the potential offset drilling runs, and identifying a subset of the potential offset drilling runs based upon the ranking. The method also includes performing a plurality of comparisons of the drilling performance of the subject drilling run against drilling performances of the subset and selecting one of a plurality of drilling system components used in the subset based at least partially upon the first comparisons.

What is claimed is: 
     
         1 . A method for selecting potential offset drilling runs to automatically evaluate a drilling performance of a subject drilling run, the method comprising:
 identifying the potential offset drilling runs based upon the subject drilling run, wherein the potential offset drilling runs are identified based upon a status of a drilling system component that is used to drill the subject drilling run;   determining a score for each of the potential offset drilling runs;   ranking the potential offset drilling runs based upon the score of each of the potential offset drilling runs;   identifying a subset of the potential offset drilling runs based upon the ranking, wherein the potential offset drilling runs in the subset are most similar to the subject drilling run;   performing a plurality of first comparisons of the drilling performance of the subject drilling run against drilling performances of the subset; and   selecting one of a plurality of drilling system components used in the subset based at least partially upon the first comparisons.   
     
     
         2 . The method of  claim 1 , further comprising determining that the subject drilling run is valid by:
 determining that the subject drilling run has drilled footage on a bit record from a well with a known geographic location; and   determining the status of the drilling system component, wherein the drilling system component comprises a drill bit, a cutter for the drill bit, a drive system, a rotary steerable system (RSS), a motor, a drilling fluid, or a combination thereof.   
     
     
         3 . The method of  claim 2 , wherein the potential offset drilling runs are identified based upon a determination that:
 the drilling system components used to drill the potential offset drilling runs are in a same family as the drilling system component used to drill the subject drilling run;   the potential offset drilling runs are within a predetermined geographical distance of the subject drilling run; and   the potential offset drilling runs have a starting depth within a predetermined depth of the subject drilling run.   
     
     
         4 . The method of  claim 1 , wherein determining the score comprises:
 determining parameter scores of a plurality of parameters; and   determining a total score based upon the parameter scores, wherein determining the total score comprises aggregating the parameter scores, and wherein the parameter scores are weighted such that some of the parameters have higher potential values than others of the parameters.   
     
     
         5 . The method of  claim 4 , wherein the parameters comprise:
 a geographic distance between the subject drilling run and the potential offset drilling runs;   a difference between a depth of the subject drilling run and the potential offset drilling runs;   a difference between a run date of the subject drilling run and the potential offset drilling runs;   an operator name of the subject drilling run matching the potential offset drilling runs;   a drilling rig used to drill the subject drilling run matching the potential offset drilling runs;   a downhole drive type of the subject drilling run matching the potential offset drilling runs;   a run direction of the subject drilling run matching the potential offset drilling runs;   a mud type of the subject drilling run matching the potential offset drilling runs; and   a well target zone formation of the subject drilling run matching the potential offset drilling runs.   
     
     
         6 . The method of  claim 1 , wherein the first comparisons are of the drilling performance of the drilling system component used in the subject drilling run against the drilling performances of the drilling system components used in the subset, and wherein the first comparisons comprise:
 a distance drilled versus an average rate of penetration (ROP);   a bit dull grade;   a percentage of drilled footage spent steering the drill bit; or   non-productive time.   
     
     
         7 . The method of  claim 1 , further comprising:
 determining a plurality of improvement scores, wherein each of the improvement scores corresponds to one of the first comparisons; and   performing a second comparison of results of the first comparisons based upon the improvement scores, wherein the one of the drilling system components is selected based at least partially upon the second comparison.   
     
     
         8 . The method of  claim 7 , wherein the improvement scores are positive in response to statistics of the subject drilling run performing better than statistics of the drilling performances of the subset, and wherein the improvement scores are negative in response to the statistics of the subject drilling run performing worse than the statistics of the drilling performances of the subset. 
     
     
         9 . The method of  claim 7 , further comprising:
 generating a first graph showing the results of the first comparisons; and   generating a second graph showing results of the second comparison.   
     
     
         10 . The method of  claim 1 , further comprising performing a wellsite action using the selected drilling system component, wherein performing the wellsite action comprises drilling a next drilling run using the selected drilling system component. 
     
     
         11 . A computing system, comprising:
 one or more processors; and   a memory system comprising one or more non-transitory computer-readable media storing instructions that, when executed by at least one of the one or more processors, cause the computing system to perform operations, the operations comprising:
 identifying potential offset drilling runs based upon a subject drilling run, wherein the potential offset drilling runs are identified based upon a status of a drilling system component that is used to drill the subject drilling run; 
 determining a score for each of the potential offset drilling runs; 
 ranking the potential offset drilling runs based upon the score of each of the potential offset drilling runs; 
 identifying a subset of the potential offset drilling runs based upon the ranking, wherein the potential offset drilling runs in the subset are most similar to the subject drilling run; 
 performing a plurality of first comparisons of a drilling performance of the subject drilling run against drilling performances of the subset; and 
 selecting one of a plurality of drilling system components used in the subset based at least partially upon the first comparisons. 
   
     
     
         12 . The computing system of  claim 11 , wherein the operations further comprise determining that the subject drilling run is valid by:
 determining that the subject drilling run has drilled footage on a bit record from a well with a known geographic location; and   determining the status of the drilling system component, wherein the drilling system component comprises a drill bit, a cutter for the drill bit, a drive system, a rotary steerable system (RSS), a motor, a drilling fluid, or a combination thereof, wherein, when the drilling system component comprises the drill bit, determining the status comprises determining that the drill bit used to drill the subject drilling run is not a green drill bit, wherein the green drilling bit has been used to drill for less than a predetermined amount of time and has less than a predetermined amount of damage, wherein the predetermined amount of time is about 2 hours if the drill bit comprises a polycrystalline diamond cutter (PDC), and/or wherein the predetermined amount of time is about 7 hours and the predetermined amount of damage comprises a bit dull grade that is less than 25% worn.   
     
     
         13 . The computing system of  claim 12 , wherein the potential offset drilling runs are identified based upon a determination that:
 the drilling system components used to drill the potential offset drilling runs are in a same family as the drilling system component used to drill the subject drilling run, wherein the family comprises a polycrystalline diamond compact (PDC) bit, a mill tooth roller cone, or a tungsten carbide insert (TCI) roller cone when the drilling system component is a drill bit, wherein the family comprises a push-the-bit or a point-the-bit when the drilling system component is the RSS, and wherein the family comprises a water-based fluid or a non-aqueous-based fluid when the drilling system component is the drilling fluid;   the potential offset drilling runs are within a predetermined geographical distance of the subject drilling run; and   the potential offset drilling runs have a starting depth within a predetermined depth of the subject drilling run.   
     
     
         14 . The computing system of  claim 11 , wherein determining the score comprises:
 determining parameter scores of a plurality of parameters; and   determining a total score based upon the parameter scores, wherein determining the total score comprises aggregating the parameter scores, and wherein the parameter scores are weighted such that some of the parameters have higher potential values than others of the parameters.   
     
     
         15 . The computing system of  claim 14 , wherein the parameters comprise:
 a geographic distance between the subject drilling run and the potential offset drilling runs, wherein a value of the geographic distance is from about 20% to about 40% of a total weight;   a difference between a depth of the subject drilling run and the potential offset drilling runs, wherein a value of the difference is from about 10% to about 20% of the total weight;   a difference between a run date of the subject drilling run and the potential offset drilling runs, wherein a value of the difference is from about 2% to about 8% of the total weight;   an operator name of the subject drilling run matching the potential offset drilling runs, wherein a value of the operator name is from about 5% to about 15% of the total weight;   a drilling rig used to drill the subject drilling run matching the potential offset drilling runs, wherein a value of the drilling rig is from about 5% to about 15% of the total weight;   a downhole drive type of the subject drilling run matching the potential offset drilling runs, wherein a value of the downhole drive type is from about 5% to about 15% of the total weight;   a run direction of the subject drilling run matching the potential offset drilling runs, wherein a value of the run direction is from about 5% to about 10% of the total weight;   a mud type of the subject drilling run matching the potential offset drilling runs, wherein a value of the mud type is from about 5% to about 10% of the total weight; and   a well target zone formation of the subject drilling run matching the potential offset drilling runs, wherein a value of the well target zone formation is from about 2% to about 8% of the total weight.   
     
     
         16 . A non-transitory computer-readable medium storing instructions that, when executed by one or more processors of a computing system, cause the computing system to perform operations, the operations comprising:
 identifying potential offset drilling runs based upon a subject drilling run, wherein the potential offset drilling runs are identified based upon a status of a drilling system component that is used to drill the subject drilling run;   determining a score for each of the potential offset drilling runs;   ranking the potential offset drilling runs based upon the score of each of the potential offset drilling runs;   identifying a subset of the potential offset drilling runs based upon the ranking, wherein the potential offset drilling runs in the subset are most similar to the subject drilling run;   performing a plurality of first comparisons of a drilling performance of the subject drilling run against drilling performances of the subset; and   selecting one of a plurality of drilling system components used in the subset based at least partially upon the first comparisons.   
     
     
         17 . The non-transitory computer-readable medium of  claim 16 , wherein the first comparisons are of the drilling performance of the drilling system component used in the subject drilling run against the drilling performances of the drilling system components used in the subset, and wherein the first comparisons comprise:
 a distance drilled versus an average rate of penetration (ROP);   a bit dull grade;   a percentage of drilled footage spent steering the drill bit; and   non-productive time.   
     
     
         18 . The non-transitory computer-readable medium of  claim 16 , wherein the operations further comprise:
 determining a plurality of improvement scores, wherein each of the improvement scores corresponds to one of the first comparisons; and   performing a second comparison of results of the first comparisons based upon the improvement scores, wherein the one of the drilling system components is selected based at least partially upon the second comparison.   
     
     
         19 . The non-transitory computer-readable medium of  claim 16 , wherein the operations further comprise performing a wellsite action using the selected drilling system component. 
     
     
         20 . The non-transitory computer-readable medium of  claim 19 , wherein the wellsite action comprises generating or transmitting a signal that instructs or causes a next drilling run to be performed using the selected drilling system component.