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Major oil and gas operators often face performance issues related to on-premises applications when dealing with huge amounts of data. A cloud-based digital solution was developed for an oil and gas company in Colombia to upgrade the production data management system (PDMS) by migrating from on-premises to a secure cloud-based environment, enhancing the performance of the solution and the remote access experience for end users. This implementation was carried out under a cloud-based infrastructure using a platform-as-a-service (PaaS) scheme, which includes middleware, database management systems, and backup services. The user access to the PDMS is through virtual desktop services, which enables load balancing of the users to avoid performance issues. The performance of the previous infrastructure was evaluated and considered when designing the new architecture, the database sizing, licensing, and integration with third-party applications. The data from the on-premises solution were analyzed and validated to guarantee correspondence with the cloud-based solution, and both solutions were run in parallel to verify consistency and reliability. The release of the cloud-based application was done in stages, with a stabilization period during which any issues could be detected and corrected. The PDMS solution was improved by faster data processing, reducing the execution time of calculation and allocation processes by 50%, while some heavy processes as data carry forward reached a 90% reduction. Enhancements included the generation of complex reports, such as hierarchy production allocation results, that did not run on the on-premises servers. As a result of this implementation, the application can be accessed from a personal computer as well as from a mobile phone, allowing the user access from any place or device, without security risks. The cloud-based solution reduced OPEX and increased flexibility due to lower maintenance costs for physical infrastructure and the cloud server's capacity based on demand.

This paper presents the successful implementation of an interwell tracer program performed in a multilayered reservoir with mature waterflooding. The objectives of the program are to evaluate water channeling in a high water cut field and, assess sweep efficiency improvements in an EOR pilot test. An extensive methodology was prepared to ensure the quality of the program. The first stage followed the screening of areas and reservoir layers with underperforming waterflooding. After that, the design stage included a selection of tracer available in the market, volume calculation and breakthrough time simulations. The execution plan defined the optimum injection rates, equipment and lab tests requirements for the monitoring and field sampling schedule. The results were being recorded in a monthly progress report and analyzed by a technical team in charge of the project. Interwell tracers made possible to confirm water channeling issues and provided information about the severity of preferential flow using the breakthrough times obtained for each reservoir layer. It was also possible to observe how changes in injection rate impacted the recovery of the tracers, creating different flow patterns at different flow rates. The six-month monitoring ended with the estimation of channel volume to design water conformance treatments. In addition, the findings from the interwell tracer conducted in the EOR pilot test showed an increase in the breakthrough time after three years of polymer flooding and, a change in flow patterns that allowed the displacement of previously bypassed oil. These results are interpreted as a measurable improvement of sweep efficiency and served as input to appraise the performance of the pilot test.