DBOS Drillbit Optimization System

To achieve minimum cost per foot with a higher degree of certainty and reduced risk, the DBOS drillbit optimization system identifies the best drill bit for the interval to be drilled. This software-based system uses offset well data to choose a fixed or roller-cone drill bit with the appropriate combination of cutting structure, gauge protection, hydraulic configuration, and other critical characteristics. Since its inception, the DBOS process has provided significant cost and time savings for operators around the world, creating a vast support database of more than 12,500 wells.

The DBOS process incorporates a thorough analysis of offset well data, including well logs, formation tops, mud logs, core analysis, rock mechanics, drilling parameters, bit records, and dull bit conditions. It comprises

• a geologic mapping program
• well log correlation and analysis software
• proprietary algorithms for rock compressive strengths, bit performance analysis, and bit selection.

Various levels of information can be analyzed by engineers, a flexibility that delivers a bit strategy based on input from a single offset well, a multiwell cross section, or a full-field mapping and regional trend analyses.

DBOS evaluation process

   1.  Evaluation of expected formation types
   2.  Offset well data gathering
   3.  Determination of unconfined compressive rock strength, effective       
        porosity, abrasion characteristics, and impact potential
   4.  Identification of potentially optimal bit types and various applicable
        characteristics
   5.  Prediction of cost per foot for each potential bit
   6.  Optimal drillbit recommendation

Operator deliverables

Various levels of the DBOS process are offered, and for each level, data is presented graphically to operators in a log plot called a bit performance analysis (BPA). The BPA evaluates key bit performance variables over the given drillability intervals, identifying which bit will be the most successful for drilling through specific single intervals or over multiple intervals. Among others, parameters include

• bit record information
• directional surveys
• real-time ROP and mud log data
• rock type and strength data
• hydraulic and mechanical energy factors.

Following the run, a postrun analysis evaluates bit performance from available data such as real-time ROP, WOB, rpm, torque, and dull bit conditions. These results provide design and application engineering feedback for continuous improvement.