The comprehensive database also includes downhole tools utilized, drilling fluid type/properties, operating parameters and the drill bit itself.ĭrill bit details include the size, manufacturer, model, serial number, part number, International Association of Drilling Contractors (IADC) bit classification code, condition after usage-known as the IADC dull grading-and reason pulled. The database also captures detailed run data, including drillstring design, surface and downhole drive system types. Originally developed in the 1980s to capture simple drilling performance and bit data, the scope of the database has expanded to capture a wealth of contextual well data, including surface location, trajectory, casing string, and formations and geology drilled. SLB’s drill bit business is largely based on an in-house database called the drilling record system (DRS) that captures global bit record performance data. It is also used to evaluate the success or failure of new bit and tool designs. It is used to analyze the effects of new technologies, such as cutter grade and shaped diamond element types. It drives decisions, such as which drill bits and tools are to be used. The collection, storage and management of offset bit run data is the crucial backbone needed to build and interpret various metrics that ultimately result in lowered well costs. Such a database, and the quality of data within it, is of significant importance to the service company and its customers, because these data are foundational for advancing drill bit technology and with it, drilling performance and well construction efficiency. Regardless of the target resource, when the drilling operation is complete, the drilling performance data are stored within a database. In this case, Company E bit runs have the highest median ROP and footage improvement scores, compared to Companies A, B, C, and D.ĭata: The foundation. The top right quadrant indicates the highest performance, while the lower left quadrant indicates the lowest performance. For each bit manufacturer, the X-Y scatter chart shows the median ROP improvement score on x-axis vs the median drilled footage improvement score on the y-axis. Aggregated results of more than 200,000 total global PDC bit runs since 2018. Automation is needed to aid performance evaluation, Fig. The ability of a bit provider to accurately quantify the performance of its products for any type of application, timeframe and location-particularly compared to those of its competitors-is paramount for performance monitoring of existing bits and for new product development. And pressure is growing to analyze and monitor the performance of all bit runs, even after the testing phase is complete, to fully understand their performance at scale and across geographies. The entire product development process may take as little as one to three months. The drill bit market is highly competitive. Meeting today’s operational challenges requires that bit designs be iterated and evaluated quickly and accurately. For a global-scale question, selecting offset runs and arriving at answers to key questions could take a week or longer. Evaluation now requires querying a vastly expanded database, exporting the data to an Excel spreadsheet format, then manually evaluating it. With the passage of time and the evolution of data science and digital technology, the scope of measurement criteria evolved to include much more than simple drilling performance and bit data. Additionally, evaluated runs were generally limited to bits in the design phase. Offset runs were selected in various ways, but they were typically chosen manually by bit engineers, meaning that offset run selection was subjective, based on personal experience and bias. Traditionally, drill bit performance was evaluated on a run-by-run basis and measured in terms of drilled footage and ROP versus similar offset runs that were both comparable to, and utilized bit designs relevant for, the test run. Drill bit designs, cutter shapes, materials and components can contribute to decreased drilling time by either increasing overall ROP or increasing footage drilled before the bit needs changing, or both. The drill bit market is only about 1% of today’s total global oilfield services market, according to 2022 industry calculations, yet bit performance is extremely important to improving overall drilling performance and reducing well construction costs.
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